PowerLogic™ PM5500 / PM5600 / PM5700 series

User manual
HRB1684301-12
08/2021

www.se.com
Legal Information
The Schneider Electric brand and any trademarks of Schneider Electric SE and its
subsidiaries referred to in this guide are the property of Schneider Electric SE or its
subsidiaries. All other brands may be trademarks of their respective owners.
This guide and its content are protected under applicable copyright laws and
furnished for informational use only. No part of this guide may be reproduced or
transmitted in any form or by any means (electronic, mechanical, photocopying,
recording, or otherwise), for any purpose, without the prior written permission of
Schneider Electric.
Schneider Electric does not grant any right or license for commercial use of the guide
or its content, except for a non-exclusive and personal license to consult it on an "as
is" basis. Schneider Electric products and equipment should be installed, operated,
serviced, and maintained only by qualified personnel.
As standards, specifications, and designs change from time to time, information
contained in this guide may be subject to change without notice.
To the extent permitted by applicable law, no responsibility or liability is assumed by
Schneider Electric and its subsidiaries for any errors or omissions in the informational
content of this material or consequences arising out of or resulting from the use of the
information contained herein.
 PowerLogic™ PM5500 / PM5600 / PM5700 series

Safety information
Important information
Read these instructions carefully and look at the equipment to become familiar
with the device before trying to install, operate, service, or maintain it. The
following special messages may appear throughout this manual or on the
equipment to warn of potential hazards or to call attention to information that
clarifies or simplifies a procedure.

The addition of either symbol to a “Danger” or “Warning” safety label indicates

that an electrical hazard exists which will result in personal injury if the
instructions are not followed.

This is the safety alert symbol. It is used to alert you to potential personal injury
hazards. Obey all safety messages that accompany this symbol to avoid possible
injury or death.

DANGER
DANGER indicates a hazardous situation which, if not avoided, will result in
death or serious injury.
Failure to follow these instructions will result in death or serious injury.

WARNING
WARNING indicates a hazardous situation which, if not avoided, could result
in death or serious injury.

CAUTION
CAUTION indicates a hazardous situation which, if not avoided, could result in
minor or moderate injury.

NOTICE
NOTICE is used to address practices not related to physical injury.

Please note
Electrical equipment should be installed, operated, serviced and maintained only
by qualified personnel. No responsibility is assumed by Schneider Electric for any
consequences arising out of the use of this material. A qualified person is one who
has skills and knowledge related to the construction, installation, and operation of
electrical equipment and has received safety training to recognize and avoid the
hazards involved.

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PowerLogic™ PM5500 / PM5600 / PM5700 series

Notices
FCC
This equipment has been tested and found to comply with the limits for a Class B
digital device, pursuant to part 15 of the FCC rules. These limits are designed to
provide reasonable protection against harmful interference in a residential
installation. This equipment generates, uses, and can radiate radio frequency
energy and, if not installed and used in accordance with the instructions, may
cause harmful interference to radio communications. However, there is no
guarantee that the interference will not occur in a particular installation. If this
equipment does cause harmful interference to radio or television reception, which
can be determined by turning the equipment off and on, the user is encouraged to
try to correct the interference by one or more of the following measures:
• Reorient or relocate the receiving antenna.
• Increase the separation between the equipment and receiver.
• Connect the equipment to an outlet on a circuit different from that to which the
receiver is connected.
• Consult the dealer or an experienced radio/TV technician for help.
The user is cautioned that any changes or modifications not expressly approved
by Schneider Electric could void the user’s authority to operate the equipment.
This digital apparatus complies with CAN ICES-3 (B) /NMB-3(B).

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 PowerLogic™ PM5500 / PM5600 / PM5700 series

About this manual

This manual discusses features of the PowerLogic™ PM5500 / PM5600 / PM5700
series power meter and provides installation and configuration instructions.
Throughout the manual, the term “meter” refers to all models of the PM5500 /
PM5600 / PM5700. All differences between the models, such as a feature specific
to one model, are indicated with the appropriate model number or description.
This manual assumes you have an understanding of power metering and are
familiar with the equipment and power system in which your meter is installed.
This manual does not provide configuration information for advanced features
where an expert user would perform advanced configuration. It also does not
include instructions on how to incorporate meter data or perform meter
configuration using energy management systems or software, other than ION
Setup. ION Setup is a free configuration tool available for download from
www.se.com.
Please contact your local Schneider Electric representative to learn what
additional training opportunities are available regarding the PM5500 / PM5600 /
PM5700 meter.
The most up-to-date documentation about your meter is available for download
from www.se.com. Scan the book QR code below to access documentation
related to the PowerLogic™ PM5500 / PM5600 / PM5700 series meters, or scan
the video QR code to access the Schneider Electric YouTube channel for videos
related to your meter.

Schneider Electric Download Center Schneider Electric YouTube Channel

Related documents

Document Number
PowerLogic™ PM5560 / PM5580 / PM5650 installation sheet GDE41422

PowerLogic™ PM5561 installation sheet HRB14028

PowerLogic™ PM5562 / PM5562MC installation sheet NVE52959

PowerLogic™ PM5563 installation sheet EAV91010

PowerLogic™ PM5RD installation sheet EAV90213

PowerLogic™ PM5570 installation sheet MFR70032

PowerLogic™ PM5660 / PM5661 / PM5760 / PM5761 MFR70030

installation sheet
Mounting adaptor kit installation sheet EAV47351

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 PowerLogic™ PM5500 / PM5600 / PM5700 series

Table of Contents
Safety precautions ....................................................................................15
Meter overview ..........................................................................................17
Overview of meter features........................................................................17
Your meter in an energy management system ............................................18
PM5500 / PM5600 / PM5700 meter models and accessories .......................19
Features differentiation matrix for PM5500 / PM5600 / PM5700
series ......................................................................................................20
Data display and analysis tools ..................................................................21
Power Monitoring Expert .....................................................................21
Power SCADA Operation ....................................................................21
Building Operation ..............................................................................21
Modbus command interface.................................................................21
Meter Insights and QR code-enabled meters ........................................22
Meter configuration ...................................................................................22
Hardware reference ..................................................................................23
Supplemental information..........................................................................23
LED indicators..........................................................................................23
Alarm / energy pulsing LED .................................................................23
Heartbeat / serial communications LED ................................................24
Ethernet communications LEDs ...........................................................24
Revenue lock LED ..............................................................................24
Terminal covers ........................................................................................24
Removing the PM5563 from the DIN rail.....................................................24
Meter wiring considerations .......................................................................26
Direct connect voltage limits ................................................................26
Balanced system considerations ..........................................................27
Neutral and ground current ..................................................................28
Communications connections....................................................................28
RS-485 wiring.....................................................................................28
Ethernet communications connections .................................................28
Digital outputs ..........................................................................................29
Digital inputs ............................................................................................29
Analog inputs ...........................................................................................29
Display ........................................................................................................30
Display overview ......................................................................................30
Default data display screen .......................................................................30
LED indicators on the display ....................................................................31
Notification icons ......................................................................................31
Meter display language .............................................................................31
Resetting the display language ............................................................32
Meter screen navigation ............................................................................32
Navigation symbols.............................................................................32
Meter screen menus overview .............................................................32
Menu tree...........................................................................................33
Data display screens ...........................................................................33
HMI setup screens....................................................................................37
Setting up the display................................................................................37

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Setting up the average voltage (Vavg) on the summary page using the
display .....................................................................................................38
Basic setup ................................................................................................40
Configuring basic setup parameters using the display .................................40
Configuring advanced setup parameters using the display...........................42
Setting up regional settings .......................................................................42
Resetting the display language ............................................................43
Setting up the screen passcodes ...............................................................43
PM5RD device hardware version Ax/Bx support for PM5563 and
PM5563RD meter models .........................................................................44
Configuring PM5563 meter for PM5RD device hardware version..................44
Configuring toroid settings for RCM using the display ..................................46
Cybersecurity.............................................................................................47
Cybersecurity overview .............................................................................47
Product defense-in-depth ..........................................................................47
Device security capabilities..................................................................48
Protected environment assumptions.....................................................49
Potential risks and compensating controls ............................................49
Default settings ........................................................................................50
User accounts and permissions .................................................................50
User account lockout policy .................................................................51
Passwords/Passcodes..............................................................................51
Default passwords/passcodes and user accounts..................................51
Changing passwords/passcodes..........................................................51
Harden the device ....................................................................................52
Enabling/Disabling communication protocols and changing port
numbers.............................................................................................52
Firmware upgrades...................................................................................54
Secure disposal guidelines........................................................................54
Secure disposal checklist ....................................................................54
Disposal, reuse, recycling....................................................................54
Webpages ..................................................................................................56
Webpages (Legacy)..................................................................................56
Applicability ........................................................................................56
Webpages overview............................................................................56
Webpages interface ............................................................................56
Accessing the meter webpages............................................................57
Default webpages ...............................................................................57
Setting the measurement range for basic parameters ............................58
User accounts ....................................................................................59
Reading device registers using the webpages.......................................60
Webpages (New)......................................................................................60
Applicability ........................................................................................60
Webpages overview............................................................................61
Webpages interface ............................................................................61
Accessing the meter webpages............................................................62
Default webpages ...............................................................................62
User accounts ....................................................................................64
Reading device registers using the webpages.......................................67
Communications .......................................................................................69

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Ethernet communications..........................................................................69
Ethernet configuration .........................................................................69
Serial communications ..............................................................................76
RS-485 network configuration ..............................................................76
BACnet/IP................................................................................................79
Supported BACnet features .................................................................80
BACnet/IP communications implementation..........................................81
Configuring BACnet/IP settings using the display ..................................81
Configuring BACnet/IP settings using the webpages..............................82
BACnet objects...................................................................................83
EtherNet/IP ..............................................................................................92
Cyclical Exchanges (Implicit Exchanges) ..............................................93
Messaging (Explicit Exchanges)...........................................................94
DNP3 .................................................................................................... 108
DNP3 device profile .......................................................................... 108
DNP3 implementation objects ............................................................ 110
Default DNP3 configuration ............................................................... 111
Configuring DNP3 setting using the display......................................... 112
Configuring DNP3 setting using the webpages .................................... 113
Modbus Ethernet gateway....................................................................... 113
Ethernet gateway implementation ...................................................... 113
Ethernet gateway configuration.......................................................... 114
Modbus TCP/IP filtering .......................................................................... 116
Modbus TCP/IP filtering implementation ............................................. 116
Access levels ................................................................................... 116
Configuring Modbus TCP/IP filtering using the webpages .................... 117
Simple Network Management Protocol (SNMP) ........................................ 117
The meter in an SNMP system........................................................... 118
SNMP implementation....................................................................... 118
SNMP trapping ................................................................................. 119
Configuring SNMP using the webpages.............................................. 120
FTP ....................................................................................................... 120
FTP file structure .............................................................................. 120
FTP file permissions.......................................................................... 120
FTP filename requirements................................................................ 121
Enabling and disabling the FTP server using the display ...................... 121
Enabling and disabling the FTP server using the webpages ................. 121
Time and timekeeping ............................................................................ 122
Setting the clock using the display............................................................ 122
Setting the meter’s clock manually using the webpages............................. 122
Configuring time and time synchronization using the webpages ................. 123
Logging ..................................................................................................... 124
Data log ................................................................................................. 124
Setting up the data log....................................................................... 124
Saving the data log contents using ION Setup..................................... 124
Setting up device log exports using the webpages ............................... 125
Alarm log ............................................................................................... 126
Maintenance log ..................................................................................... 126
Inputs / outputs ........................................................................................ 127
I/O overview ........................................................................................... 127

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Digital input applications.......................................................................... 127

Digital input wiring considerations ...................................................... 127
WAGES monitoring ........................................................................... 127
Configuring digital inputs using ION Setup .......................................... 128
Configuring digital inputs using the display.......................................... 129
Input metering ........................................................................................ 130
Configuring input metering using ION Setup........................................ 130
Configuring input metering using the display ....................................... 131
Demand measurements for input metering.......................................... 132
Viewing input metering data through the meter’s display ...................... 133
Digital output applications ....................................................................... 133
Digital output application example ...................................................... 133
Configuring digital outputs using ION Setup ........................................ 133
Configuring digital outputs using the display........................................ 134
Energy pulsing ....................................................................................... 135
Configuring the alarm / energy pulsing LED using the display ............... 136
Configuring the alarm / energy pulsing LED or digital output for
energy pulsing using ION Setup ......................................................... 136
Analog inputs ......................................................................................... 137
Configuring analog inputs using the display ........................................ 137
Resets....................................................................................................... 141
Meter resets ........................................................................................... 141
Meter Initialization............................................................................. 141
Performing global resets using the display ................................................ 141
Performing single resets using the display ................................................ 141
Performing user account resets using the display...................................... 142
Alarms....................................................................................................... 144
Alarms overview ..................................................................................... 144
Alarm types............................................................................................ 144
Unary alarms.......................................................................................... 144
Available unary alarms ...................................................................... 144
Digital alarms ......................................................................................... 145
Available digital alarms...................................................................... 145
Standard alarms ..................................................................................... 145
Example of over and under setpoint (standard) alarm operation............ 146
Maximum allowable setpoint .............................................................. 147
Available standard alarms ................................................................. 147
Power factor (PF) alarms................................................................... 149
Phase loss alarm .............................................................................. 150
Logic alarms .......................................................................................... 150
Custom alarms ....................................................................................... 151
Custom alarm parameter list .............................................................. 151
Disturbance (sag/swell) alarms ................................................................ 152
Alarm priorities ....................................................................................... 152
Alarm setup overview.............................................................................. 153
Setting up alarms using the display .................................................... 153
Setting up alarms using ION Setup..................................................... 153
Unary alarm setup parameters ........................................................... 154
Digital alarm setup parameters .......................................................... 154
Standard (1-Sec) alarm setup parameters .......................................... 154
Setting up logic alarms using ION Setup ............................................. 155
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Setting up custom alarms using ION Setup ......................................... 156

Setting up disturbance alarms using display........................................ 157
LED alarm indicator ................................................................................ 158
Configuring the LED for alarms using the display................................. 158
Configuring the LED for alarms using ION Setup ................................. 158
Alarm display and notification .................................................................. 158
Email on alarm ....................................................................................... 159
Implementation and default configuration............................................ 159
Email on alarm examples .................................................................. 160
Configuring the email on alarm feature using the webpages ................. 161
Active alarms list and alarm history log ..................................................... 162
Viewing active alarm details using the display ..................................... 162
Viewing alarm history details using the display .................................... 163
Viewing alarms counters using the display .......................................... 163
Acknowledging high-priority alarms using the display ................................ 163
Resetting alarms using ION Setup ........................................................... 163
Multi-tariffs ............................................................................................... 165
Multi-tariff............................................................................................... 165
Multi-tariff implementation ....................................................................... 165
Command mode overview....................................................................... 165
Time of day mode overview ..................................................................... 166
Time of day mode tariff validity ........................................................... 166
Time of day tariff creation methods ..................................................... 166
Input mode overview............................................................................... 167
Digital input assignment for input control mode.................................... 167
Tariff setup ............................................................................................. 169
Configuring input mode tariffs using the display ................................... 169
Measurements ........................................................................................ 171
Instantaneous measurements ................................................................. 171
Residual current ..................................................................................... 171
Energy measurements ............................................................................ 172
Configuring the energy scaling using ION Setup.................................. 172
Preset energy......................................................................................... 173
Configuring the preset energy using ION Setup ................................... 173
Min/max values ...................................................................................... 174
Demand measurements.......................................................................... 174
Power demand ................................................................................. 174
Current demand................................................................................ 177
Predicted demand............................................................................. 177
Peak demand ................................................................................... 177
Input Metering Demand ..................................................................... 178
Setting up demand calculations using the display ................................ 178
Power and power factor .......................................................................... 179
Current phase shift from voltage......................................................... 180
Real, reactive and apparent power (PQS) ........................................... 180
Power factor (PF).............................................................................. 181
Power factor sign convention ............................................................. 181
Power factor register format............................................................... 182
Timers ................................................................................................... 184
Power quality ........................................................................................... 185

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PowerLogic™ PM5500 / PM5600 / PM5700 series

Power quality measurements .................................................................. 185

Harmonics overview ............................................................................... 185
Voltage crest factor ................................................................................. 185
K-factor.................................................................................................. 186
Total harmonic distortion %...................................................................... 186
Total demand distortion ........................................................................... 186
Harmonic content calculations ................................................................. 186
THD% calculations ................................................................................. 186
thd calculations ...................................................................................... 187
TDD calculations .................................................................................... 187
Viewing harmonics using the display ........................................................ 187
Viewing TDD, K-factor and Crest factor data ............................................. 188
Viewing THD/thd using the display ........................................................... 189
Waveform capture .................................................................................. 189
Overview of waveform capture ........................................................... 189
Configuring waveform capture using ION Setup .................................. 190
Configuring waveform capture using the display.................................. 191
Configuring sag/swell using ION Setup ............................................... 192
Configuring sag/swell using the display............................................... 192
Monitoring waveform capture on meter’s webpages ............................ 193
Maintenance ............................................................................................ 196
Maintenance overview ............................................................................ 196
Lost user access .................................................................................... 196
Diagnostics information........................................................................... 196
Control power (auxiliary power) interruption event ..................................... 196
Acknowledging control power (auxiliary power) interruption event
using the display ............................................................................... 197
Wrench icon ........................................................................................... 197
LED indicators........................................................................................ 198
Phasors ................................................................................................. 198
Phasor screens................................................................................. 198
Meter memory ........................................................................................ 199
Meter battery.......................................................................................... 199
Firmware version, model and serial number.............................................. 199
Firmware upgrades................................................................................. 200
Firmware upgrade methods ............................................................... 201
Technical assistance............................................................................... 206
Verifying accuracy................................................................................... 207
Overview of meter accuracy .................................................................... 207
Accuracy test requirements ..................................................................... 207
Energy pulsing.................................................................................. 208
Meter settings for accuracy testing ........................................................... 208
Verifying accuracy test ............................................................................ 208
Required pulses calculation for accuracy verification testing................. 210
Total power calculation for accuracy verification testing........................ 210
Percentage error calculation for accuracy verification testing................ 210
Accuracy verification test points ............................................................... 211
Energy pulsing considerations ................................................................. 211
VT and CT considerations........................................................................ 211
Example calculations .............................................................................. 212
Typical sources of test errors ................................................................... 213
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Revenue ................................................................................................... 214

Revenue metering overview .................................................................... 214
Revenue metering components ............................................................... 214
Revenue firmware security features ......................................................... 214
Protected setup parameters and functions................................................ 214
Revenue-locking summary ...................................................................... 216
Revenue locking..................................................................................... 216
Locking or unlocking the PM5561 / PM5661 / PM5761......................... 216
Revenue lock switch ......................................................................... 217
Locking and unlocking your meter using the hardware switch ............... 217
Device specifications .............................................................................. 219
Restoration of temporarily disabled configuration settings in
webpages ................................................................................................. 225
China Standard Compliance ................................................................. 226

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Safety precautions PowerLogic™ PM5500 / PM5600 / PM5700 series

Safety precautions
Installation, wiring, testing and service must be performed in accordance with all
local and national electrical codes.

DANGER
HAZARD OF ELECTRIC SHOCK, EXPLOSION, OR ARC FLASH
• Apply appropriate Personal Protective Equipment (PPE) and follow safe
electrical work practices. See NFPA 70E, CSA Z462 or other local
standards.
• Turn off all power supplying this device and the equipment in which it is
installed before working on or in the equipment.
• Always use a properly rated voltage sensing device to confirm that all power
is off.
• Follow guidelines in the Wiring section of the related Installation Sheet.
• Assume communications and I/O wiring are hazardous live until determined
otherwise.
• Do not exceed the maximum ratings of this device.
• Do not short secondary terminals of Voltage Transformer (VT).
• Do not open secondary terminals of Current Transformer (CT).
• Ground secondary circuit of CTs.
• Do not use the data from the meter to confirm power is off.
• Replace all devices, doors and covers before turning on power to this
equipment.
Failure to follow these instructions will result in death or serious injury.

NOTE: See IEC 60950-1 for more information on communications and I/O
wiring connected to multiple devices.

WARNING
UNINTENDED OPERATION
• Do not use this device for critical control or protection of persons, animals,
property or equipment.

• Do not use this device if a wrench icon appears on the top left corner
of the display screen or if the value under Meter Status is not “OK”.
Failure to follow these instructions can result in death, serious injury, or
equipment damage.

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PowerLogic™ PM5500 / PM5600 / PM5700 series Safety precautions

WARNING
POTENTIAL COMPROMISE OF SYSTEM AVAILABILITY, INTEGRITY, AND
CONFIDENTIALITY
• Change default passwords/passcodes to help prevent unauthorized access
to device settings and information.
• Disable unused ports/services and default accounts, where possible, to
minimize pathways for malicious attacks.
• Place networked devices behind multiple layers of cyber defenses (such as
firewalls, network segmentation, and network intrusion detection and
protection).
• Use cybersecurity best practices (for example: least privilege, separation of
duties) to help prevent unauthorized exposure, loss, modification of data and
logs, interruption of services, or unintended operation.
Failure to follow these instructions can result in death, serious injury, or
equipment damage.

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Meter overview PowerLogic™ PM5500 / PM5600 / PM5700 series

Meter overview
Overview of meter features
The PowerLogic™ PM5500 / PM5600 / PM5700 power meters offer value for the
demanding needs of your energy monitoring and cost management applications.
The PM5500 / PM5600 / PM5700 complies to Class 0.2S accuracy standards and
feature high quality, reliability and affordability in a compact and easy to install
format.
NOTE: Not all features are available on all models.

Hardware
• A fourth current input for direct and accurate measurement of neutral current,
to help avoid device overload and network outage.
• Two digital outputs for control and energy pulsing applications.
• Four digital inputs/two digital inputs with input metering support for WAGES
monitoring applications.
• LED that can be used for energy pulsing applications.
Applicable for specific meter models:
• Two Residual Current Measurement (RCM) inputs.
• Two analog inputs to interpret an incoming analog current signal from
transducers and provide the resulting scaled value.
• Low-voltage DC control power.

Display and user interface

• Onboard webpages for displaying real-time, logged data and waveform
capture information using a web browser.
• Multiple language support: The back-lit anti-glare display screen can be
switched to display meter information in one of the supported languages (on
models with a display screen).
• Graphical display of harmonics and phasor diagrams on models with an
integrated or optional remote display.
• QR codes with embedded data for viewing meter information using Meter
Insights.

Alarming
• Extensive alarming options like unary, digital, standard, logic, custom, and
disturbance alarms.
• The ability to send emails with alarm information.

Communications
• Dual Ethernet switched ports allow fast Ethernet interconnection to other
PM5500 / PM5600 / PM5700 meters using only one IP switch.
• Ethernet gateway functionality, allowing a Modbus master using Modbus TCP
to communicate through the meter to downstream serial devices using
Modbus RTU.
• Support for a variety of Ethernet protocols, such as Modbus TCP, BACnet/IP,
EtherNet/IP and DNP3. All the Ethernet protocols can be used at the same
time.

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PowerLogic™ PM5500 / PM5600 / PM5700 series Meter overview

• Enhanced Modbus security using TCP/IP filtering to set the specific IP

addresses that are permitted to access the meter.

Measurements and logging

• 4-quadrant, Class 0.2S accurate energy metering.
• Present, last, predicted and peak (maximum) demand using a selection of
demand calculation methods.
• Highly accurate 1-second measurements.
• Onboard data logging support for up to 14 selectable parameters.
• Complete harmonic distortion metering, recording and realtime reporting, up
to the 63rd harmonic for all voltage and current inputs.
• Recording of each new minimum and new maximum value.

Revenue and tariffs

• Multiple tariff support (8 tariffs) for monitoring energy usage.
• Models with features to help you comply with revenue and billing standards.

Compliance to international standards

• IEC 62053-22 Class 0.5S / Class 0.2S
• ANSI C12.20 Class 0.2
• IEC 61557-12 PMD/S/K70/0.2
• IEC 62053-23
• IEC 62052-11
• MID, EN50470-1/3 – Annex B and Annex D
• CE as per IEC 61010-1 Ed.3
• cULus as per UL 61010-1 Ed.3
• BACnet/IP - BTL listed (B-ASC)
• EtherNet/IP - ODVA certified

Your meter in an energy management system

You can use the meter as a stand-alone device, but its extensive capabilities are
fully realized when used as part of an energy management system.

18 HRB1684301-12
Meter overview PowerLogic™ PM5500 / PM5600 / PM5700 series

Inputs / outputs Alarming and

alerting
Highly accurate
Data and event
metering
logging

Simple Power quality

configuration monitoring
Measure

Understand

Easy access
to information

Act
Energy by tariff Energy
efficiency

Asset and network Configurable

management security

Perform basic setup using the LCD display, the meter Configure the meter to help protect against unauthorized
webpages or ION Setup configuration and access to your meter’s data

Access highly accurate measurements and calculations for a Improve energy efficiency and track compliance to green
wide variety of power system values standards

Use the onboard I/O for non-critical control, WAGES and

input metering, energy pulsing and system monitoring Help prolong asset life with proactive network management
(for example, breaker status)

Receive notifications of predefined meter and system events Track energy by tariff and perform cost allocation/tenant billing
or create custom alarms
Easily access information after basic configuration using:
Monitor harmonic distortion up to the 63rd harmonic for all
• a variety of industry-standard protocols
voltage and current inputs
• software such as Power Monitoring Expert, PowerSCADA
Expert, and Building Operation
Log data in a number of onboard default logs, or customize • the meter’s internal webpages
your meter to log other parameters, and access that • the optional remote display (DIN models)
information using software or webpages • from downstream devices by using the meter as a gateway
• data embedded in QR codes on the meter’s display

PM5500 / PM5600 / PM5700 meter models and accessories

The meter is available in several different models with optional accessories that
provide various mounting options.

Meter models
Model Commercial reference Description

PM5560 METSEPM5560 Front panel mount, integrated display, 96 x 96 mm form factor, fits in
a 1/4 DIN mounting hole.

PM5561 METSEPM5561 Same as PM5560, except the meter is calibrated to comply to strict
MID standards.
PM5562 METSEPM5562 Same as PM5560 with the addition of a sealable hardware lock
which prevents modification of revenue related settings and
functions.
PM5562MC METSEPM5562MC Same as PM5562, except that it is sealed at the factory.

PM5563 METSEPM5563 Transducer (TRAN) model, no display, mounts on a standard TS35

top hat style DIN rail.

PM5563RD METSEPM5563RD Same as PM5563, except that it is package with a remote display
(PM5RD).

PM5650 METSEPM5650 Same as PM5560 with the addition of sag/swell detection and
waveform capture.

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PowerLogic™ PM5500 / PM5600 / PM5700 series Meter overview

Model Commercial reference Description

PM5580 METSEPM5580 Same as PM5560, except for 20 – 60 V DC control power (LVDC).

PM5570 METSEPM5570 Front panel mount, integrated display, 96 x 96 mm form factor, fits in
a 1/4 DIN mounting hole with two digital inputs and two analog
inputs.

PM5660 METSEPM5660 Front panel mount, integrated display, 96 x 96 mm form factor, fits in
a 1/4 DIN mounting hole with two digital inputs and two RCM inputs.

PM5661 METSEPM5661 Same as PM5660, except the meter is calibrated to comply to strict
MID standards.
PM5760 METSEPM5760 Same as PM5660 with the addition of sag/swell detection and
waveform capture.

PM5761 METSEPM5761 Same as PM5760, except the meter is calibrated to comply to strict
MID standards.

Meter accessories
Model Commercial reference Description

PM5RD METSEPM5RD The remote meter display can be used with DIN meters. It has the
same buttons, icons and LEDs as the display on an integrated
meter, and is powered by the connection to the DIN meter.
NOTE: A remote display cannot be used with meters that have
an integrated display.

See the PM5500 / PM5600 / PM5700 catalog pages, available from www.se.com,
or consult your local Schneider Electric representative for information about
mounting adapters available for your meter.

Features differentiation matrix for PM5500 / PM5600 / PM5700

series
NOTE: Features which are not listed is common across all meter models.

Feature PM5560 PM5561 PM5562 PM5563 PM5650 PM5570 PM5580 PM5660 PM5661 PM5760 PM5761
PM5562MC PM5563RD
100 – 180 V AC; ✔ ✔ ✔ ✔ ✔ ✔ – ✔ ✔ ✔ ✔
125 – 250 V DC
control power

20 – 60 V DC – – – – – – ✔ – – – –
control power

Digital inputs 4 4 4 4 4 2 4 2 2 2 2
(S1 to (S1 to (S1 to S4) (S1 to S4) (S1 to (S1 & (S1 to (S1 & (S1 & (S1 & (S1 &
S4) S4) S4) S2) S4) S2) S2) S2) S2)

RCM inputs – – – – – – – 2 2 2 2
(I5 & I6) (I5 & I6) (I5 & I6) (I5 & I6)

Analog inputs – – – – – 2 – – – – –
4 – 20 mA (A1 &
A2)

Digital outputs 2 2 2 2 2 2 2 2 2 2 2
(D1 & (D1 & (D1 & D2) (D1 & D2) (D1 & (D1 & (D1 & (D1 & (D1 & (D1 & (D1 &
D2) D2) D2) D2) D2) D2) D2) D2) D2)

DNP3 over ✔ ✔ – ✔ ✔ ✔ ✔ ✔ ✔ ✔ ✔
Ethernet
Sag/Swell – – – – ✔ – – – – ✔ ✔
detection
Waveform – – – – ✔ – – – – ✔ ✔
capture

Digital alarm 4 4 4 4 4 2 4 2 2 2 2

Standard alarm 29 29 29 29 29 29 29 33 33 33 33

20 HRB1684301-12
Meter overview PowerLogic™ PM5500 / PM5600 / PM5700 series

Feature PM5560 PM5561 PM5562 PM5563 PM5650 PM5570 PM5580 PM5660 PM5661 PM5760 PM5761
PM5562MC PM5563RD
Disturbance – – – – 2 – – – – 2 2
alarm
MID – ✔ – – – – – – ✔ – ✔

Data display and analysis tools

Power Monitoring Expert
EcoStruxure™ Power Monitoring Expert is a complete supervisory software
package for power management applications.
The software collects and organizes data gathered from your facility’s electrical
network and presents it as meaningful, actionable information via an intuitive web
interface.
Power Monitoring Expert communicates with devices on the network to provide:
• Real-time monitoring through a multi-user web portal
• Trend graphing and aggregation
• Power quality analysis and compliance monitoring
• Preconfigured and custom reporting
See the EcoStruxure™ Power Monitoring Expert online help for instructions on
how to add your device into its system for data collection and analysis.

Power SCADA Operation

EcoStruxure™ Power SCADA Operation is a complete real-time monitoring and
control solution for large facility and critical infrastructure operations.
It communicates with your device for data acquisition and real-time control. You
can use Power SCADA Operation for:
• System supervision
• Real-time and historical trending, event logging
• Real-time and historical trending, event logging and waveform capture
• PC-based custom alarms
See the EcoStruxure™ Power SCADA Operation online help for instructions on
how to add your device into its system for data collection and analysis.

Building Operation
Struxtureware™ Building Operation is a complete software solution for integrated
monitoring, control, and management of energy, lighting, fire safety, and HVAC.
It natively supports the major communication standards in building automation and
security management, including TCP/IP, LonWorks, BACnet, Modbus and
Ethernet.

Modbus command interface

Most of the meter’s real-time and logged data, as well as basic configuration and
setup of meter features, can be accessed and programmed using a Modbus
command interface as published in the meter’s Modbus register list.
This is an advanced procedure that should only be performed by users with
advanced knowledge of Modbus, their meter, and the power system being
monitored. For further information on the Modbus command interface, contact
Technical Support.

HRB1684301-12 21
PowerLogic™ PM5500 / PM5600 / PM5700 series Meter overview

See your meter’s Modbus register list at www.se.com for the Modbus mapping
information and basic instructions on command interface.

Meter Insights and QR code-enabled meters

The QR code feature allows you to view meter data using the Meter Insights
website by scanning a QR code on the meter’s display.
The meter dynamically generates the selected QR code when you navigate to the
appropriate screen. The data embedded in the QR code is displayed in Meter
Insights using the web browser on your smartphone or tablet.
You can register with Meter Insights to store the results of your scans, which
allows you to view:
• Detailed energy usage patterns
• Trends in energy consumption
• Alarms for possible issues
Meter Insights also displays notifications of possible issues or improvements you
can make to the meter’s configuration or your electrical network. Plus you can
share information with colleagues and run reports on stored data.
See the Meter Insights QR code feature quick start guide, available from
www.se.com, for information on using Meter Insights and the QR code feature on
your meter.

Meter configuration
Meter configuration can be performed through the display (if your meter is
equipped with one), the meter webpages or PowerLogic™ ION Setup.
ION Setup is a meter configuration tool that can be downloaded for free at
www.se.com.
See the ION Setup online help or in the ION Setup device configuration guide. To
download a copy, go to www.se.com and search for ION Setup device
configuration guide.

22 HRB1684301-12
Hardware reference PowerLogic™ PM5500 / PM5600 / PM5700 series

Hardware reference
Supplemental information
This document is intended to be used in conjunction with the installation sheet that
ships in the box with your device and accessories.
See your device’s installation sheet for information related to installation.
See your product’s catalog pages at www.se.com for information about your
device, its options and accessories.
You can download updated documentation from www.se.com or contact your local
Schneider Electric representative for the latest information about your product.

LED indicators
The LED indicators alert or inform you of meter activity or status.

Models with a display (and DIN model

the optional remote display)

A Alarm / energy pulsing LED

B Heartbeat / serial
communications LED

All models
C Ethernet communications
LEDs
D Lock status LED

Alarm / energy pulsing LED

The alarm / energy pulsing LED can be configured for alarm notification or energy
pulsing.
When configured for alarm notification, this LED flashes when a high, medium or
low priority alarm is active. The LED provides a visual indication of an active alarm
condition or an inactive but unacknowledged high priority alarm.
When configured for energy pulsing, this LED flashes at a rate proportional to the
amount of energy consumed. This is typically used to verify the power meter’s
accuracy.
NOTE: The alarm / energy pulsing LED on the MID model is permanently set
for energy pulsing and cannot be disabled or used for alarms.

HRB1684301-12 23
PowerLogic™ PM5500 / PM5600 / PM5700 series Hardware reference

Heartbeat / serial communications LED

The heartbeat / serial communications LED blinks to indicate the meter’s
operation and serial Modbus communications status.
The LED blinks at a slow, steady rate to indicate the meter is operational. The LED
flashes at a variable, faster rate when the meter is communicating over a Modbus
serial communications port.
You cannot configure this LED for other purposes.
NOTE: A heartbeat LED that remains lit and does not blink (or flash) can
indicate a problem. In this case, power down the meter and reapply power. If
the LED still does not blink or flash, contact Technical Support.

Ethernet communications LEDs

The meter has two LEDs per port for Ethernet communications.
The Link LED is on when there is a valid Ethernet connection. The Act (active)
LED flashes to indicate the meter is communicating through the Ethernet port.
You cannot configure these LEDs for other purposes.

Revenue lock LED

The revenue lock LED indicates the lock status on the PM5562 and PM5562MC.
The LED turns steady green when the revenue lock is enabled.

Terminal covers
The voltage, current and control/auxiliary power terminal covers help prevent and
detect tampering with the meter’s voltage, current measurement inputs and
control/auxiliary power inputs.
The terminal covers enclose the terminals, the conductor fixing screws and a
length of the external conductors and their insulation. The terminal covers are to
be secured by tamper-resistant meter seals.
These covers are included for meter models where sealable voltage, current and
control/auxiliary power covers are required to comply with revenue or regulatory
standards.
The meter terminal covers must be installed by a qualified installer.
Refer to your meter's installation sheet or the instructions that came with your
terminal covers for instructions on installing the terminal covers.

Removing the PM5563 from the DIN rail

Follow these instructions to remove the meter from a TS35 Top-Hat style DIN rail.
Installation, wiring, testing and service must be performed in accordance with all
local and national electrical codes.

24 HRB1684301-12
Hardware reference PowerLogic™ PM5500 / PM5600 / PM5700 series

DANGER
HAZARD OF ELECTRIC SHOCK, EXPLOSION, OR ARC FLASH
• Apply appropriate Personal Protective Equipment (PPE) and follow safe
electrical work practices. See NFPA 70E, CSA Z462 or other local
standards.
• Turn off all power supplying this device and the equipment in which it is
installed before working on or in the equipment.
• Always use a properly rated voltage sensing device to confirm that all power
is off.
• Do not exceed the maximum ratings of this device.
• Do not short secondary terminals of Voltage Transformer (VT).
• Do not open secondary terminals of Current Transformer (CT).
• Ground secondary circuit of CTs.
• Replace all devices, doors and covers before turning on power to this
equipment.
Failure to follow these instructions will result in death or serious injury.

1. Turn off all power supplying this device and the equipment in which it is
installed before working on it.
2. Always use a properly rated voltage sensing device to confirm that all power
is off.
3. Insert a flat-tip screwdriver into the DIN release clip. Pull down the clip until
you hear an audible click and the DIN clip is unlocked.

ICK
CL

4. Swing the meter out and upwards to remove the meter.

HRB1684301-12 25
PowerLogic™ PM5500 / PM5600 / PM5700 series Hardware reference

Meter wiring considerations

Direct connect voltage limits
You can connect the meter’s voltage inputs directly to the phase voltage lines of
the power system if the power system’s line-to-line or line-to-neutral voltages do
not exceed the meter’s direct connect maximum voltage limits.
The meter's voltage measurement inputs are rated by the manufacturer for up to
400 V L-N / 690 V L-L. However, the maximum voltage allowed for direct
connection may be lower, depending on the local electrical codes and regulations.
In US and Canada the maximum voltage on the meter voltage measurement
inputs may not exceed 347 V L-N / 600 V L-L.
If your system voltage is greater than the specified direct connect maximum
voltage, you must use VTs (voltage transformers) to step down the voltages.

Power system Meter setting Symbol Direct connect Direct connect # of VTs (if
description maximum (UL) maximum (IEC) required)

Single-phase 2-wire 1PH2W LN 480 V L-N 480 V L-N 1 VT

line-to-neutral

Single-phase 2-wire 1PH2W LL 600 V L-L 600 V L-L 1 VT

line-to-line

Single-phase 3-wire 1PH3W LL with N 347 V L-N / 600 V 400 V L-N / 690 V 2 VT
line-to-line with L-L L-L
neutral

3-phase 3-wire 3PH3W Dlt Ungnd 600 V L-L 600 V L-L 2 VT

Delta ungrounded

3-phase 3-wire 3PH3W Dlt Crnr 600 V L-L 600 V L-L 2 VT

Delta corner Gnd
grounded

3-phase 3-wire Wye 3PH3W Wye Ungnd 600 V L-L 600 V L-L 2 VT
ungrounded

26 HRB1684301-12
Hardware reference PowerLogic™ PM5500 / PM5600 / PM5700 series

Power system Meter setting Symbol Direct connect Direct connect # of VTs (if
description maximum (UL) maximum (IEC) required)

3-phase 3-wire Wye 3PH3W Wye Gnd 600 V L-L 600 V L-L 2 VT
grounded

3-phase 3-wire Wye 3PH3W Wye Res 600 V L-L 600 V L-L 2 VT
resistance-grounded Gnd

3-phase 4-wire open 3PH4W Opn Dlt Ctr 240 V L-N / 415 V 240 V L-N / 415 V 3 VT
Delta center-tapped Tp L-N / 480 V L-L L-N / 480 V L-L

3-phase 4-wire 3PH4W Dlt Ctr Tp 240 V L-N / 415 V 240 V L-N / 415 V 3 VT
Delta center-tapped L-N / 480 V L-L L-N / 480 V L-L

3-phase 4-wire 3PH4W Wye Ungnd 347 V L-N / 600 V 347 V L-N / 600 V 3 VT or 2 VT
ungrounded Wye L-L L-L

3-phase 4-wire 3PH4W Wye Gnd 347 V L-N / 600 V 400 V L-N / 690 V 3 VT or 2 VT
grounded Wye L-L L-L

3-phase 4-wire 3PH4W Wye Res 347 V L-N / 600 V 347 V L-N / 600 V 3 VT or 2 VT
resistance-grounded Gnd L-L L-L
Wye

Balanced system considerations

In situations where you are monitoring a balanced 3-phase load, you may choose
to connect only one or two CTs on the phase(s) you want to measure, and then
configure the meter so it calculates the current on the unconnected current
input(s).
NOTE: For a balanced 4-wire Wye system, the meter’s calculations assume
that there is no current flowing through the neutral conductor.

HRB1684301-12 27
PowerLogic™ PM5500 / PM5600 / PM5700 series Hardware reference

Balanced 3-phase Wye system with 2 CTs

The current for the unconnected current input is calculated so that the vector sum
for all three phases equal zero.

Balanced 3-phase Wye or Delta system with 1CT

The currents for the unconnected current inputs are calculated so that their
magnitude and phase angle are identical and equally distributed, and the vector
sum for all three phase currents equal zero.
NOTE: You must always use 3 CTs for 3-phase 4-wire center-tapped Delta or
center-tapped open Delta systems.

Neutral and ground current

The fourth current input (I4) can be used to measure current flow (In) in the neutral
conductor, which can then be used to calculate residual current. The meter refers
to residual current as ground current (Ig).
For 4-wire Wye systems, ground current is calculated as the difference between
the measured neutral current and the vector sum of all measured phase currents.

Communications connections
RS-485 wiring
Connect the devices on the RS-485 bus in a point-to-point configuration, with the
(+) and (-) terminals from one device connected to the corresponding (+) and (-)
terminals on the next device.

RS-485 cable
Use a shielded 2 twisted pair or 1.5 twisted pair RS-485 cable to wire the devices.
Use one twisted pair to connect the (+) and (-) terminals, and use the other
insulated wire to connect the C terminals
The total distance for devices connected on an RS-485 bus should not exceed
1200 m (4000 ft).

RS-485 terminals
C Common. This provides the voltage reference (zero volts) for the data plus and data minus
signals

Shield. Connect the bare wire to this terminal to help suppress signal noise that may be
present. Ground the shield wiring at one end only (either at the master or the last slave
device, but not both.

- Data minus. This transmits/receives the inverting data signals.

+ Data plus. This transmits/receives the non-inverting data signals.

NOTE: If some devices in your RS-485 network do not have the Common
terminal, use the bare wire in the RS-485 cable to connect the Common
terminal from the meter to the shield terminal on the devices that do not have
the Common terminal.

Ethernet communications connections

Use a Cat 5 cable to connect the meter’s Ethernet port.

28 HRB1684301-12
Hardware reference PowerLogic™ PM5500 / PM5600 / PM5700 series

Your Ethernet connection source should be installed in a location that minimizes

the overall Ethernet cable routing length.

Digital outputs
The meter is equipped with two Form A digital outputs (D1, D2).
You can configure the digital outputs for use in the following applications:
• switching applications, for example, to provide on/off control signals for
switching capacitor banks, generators, and other external devices and
equipment
• demand synchronization applications, where the meter provides pulse signals
to the input of another meter to control its demand period
• energy pulsing applications, where a receiving device determines energy
usage by counting the kWh pulses coming from the meter’s digital outputs
Refer to Device specifications, page 219 for the voltage limits of the digital
outputs. For higher voltage applications, use an external relay as the switching
circuit.

Digital inputs
The meter is equipped with four digital inputs (S1 to S4) or two digital inputs (S1 &
S2)*.
NOTE: *Available in specific meter models. Refer to Features differentiation
matrix for PM5500 / PM5600 / PM5700 series, page 20 for the availability.
You can configure the digital inputs for use in status monitoring or input metering
applications.
The meter’s digital inputs require an external voltage source to detect the digital
input’s on/off state. The meter detects an on state if the external voltage appearing
at the digital input is within its operating range.
Refer to Device specifications, page 219 for the external voltage sources to detect
the digital input’s on/off state.

Analog inputs
The meter is equipped with two analog inputs (A1 & A2)*.
NOTE: *Available in specific meter models. Refer to Features differentiation
matrix for PM5500 / PM5600 / PM5700 series, page 20 for the availability.
The analog inputs interpret an incoming analog current signal from transducers.
For analog input operation, the meter processes an analog input signal and
provides the resulting scaled value.
The meter measures the current using standard 4 - 20 mA analog transducers.

HRB1684301-12 29
PowerLogic™ PM5500 / PM5600 / PM5700 series Display

Display
Display overview
The display (integrated or remote) lets you use the meter to perform various tasks
such as setting up the meter, displaying data screens, acknowledging alarms, or
performing resets.

A Navigation / menu selection

G F E buttons
B Heartbeat / communications
LED (green)

C Alarm / energy pulsing LED

(orange)

D Navigation symbols or menu

D options
H
E Right notification area
C
B F Screen title

A G Left notification area

H Cursor

Default data display screen

The default data display screen varies depending on the meter model.
The Summary screen is the default screen for all meter models except PM5561 /
PM5661 / PM5761.
The Summary screen displays real-time values for average voltage and current
(Vavg, Iavg), total power (Ptot) and energy consumption (E Del).

The Power System screen is the default screen for PM5561 / PM5661 / PM5761
meter models.

A Accumulated real energy (delivered +

received)

B System frequency

C Active tariff
D Power system setting

E Control power (auxiliary power) interruption

event icon
F Locked / unlocked icon

30 HRB1684301-12
Display PowerLogic™ PM5500 / PM5600 / PM5700 series

LED indicators on the display

The display has two LED indicators.

A Alarm / energy pulsing LED (orange)

B Heartbeat / communications LED (green)

NOTE: For PM5561 / PM5661 / PM5761 meter models, the alarm / energy
pulsing LED is factory set for energy pulsing only and cannot be modified or
disabled.

Notification icons
To alert you about meter state or events, notification icons appear at the top left or
top right corner of the display screen.

Icon Description

The wrench icon indicates that the power meter is in an over voltage
condition or requires maintenance. It could also indicate that the
energy LED is in an overrun state.

The alarm icon indicates an alarm condition has occurred.

The meter’s hardware and / or firmware lock is enabled.

The icon indicates that a control power (auxiliary power) interruption

(Displayed only in MID event has occurred.
compliance meter models)

Meter display language

You can configure the meter to display the information on the display screen in
one of several languages.
The following languages are available:
• English
• French
• Spanish
• German
• Italian
• Portuguese
• Russian
• Chinese

HRB1684301-12 31
PowerLogic™ PM5500 / PM5600 / PM5700 series Display

Resetting the display language

To reset the meter to the default language (English), press and hold the outermost
two buttons for 5 seconds.

Meter screen navigation

The meter’s buttons and display screen allow you to navigate data and setup
screens, and to configure the meter’s setup parameters.

A. Press the button below the

appropriate menu to view
that screen
B. Press the right arrow to
view more screens
C. In setup mode, a small
right arrow indicates the
selected option
D. In setup mode, a small
down arrow indicates that
there are additional
parameters to display. The
down arrow disappears
when there are no more
parameters to display.
E. In setup mode, press the
button under Edit to
change that setting. If the
item is read-only, cannot
be configured with the
meter’s existing setup, or
can only be configured
using software, Edit
disappears.

Navigation symbols
Navigation symbols indicate the functions of the associated buttons on your
meter’s display.

Symbol Description Actions

Right arrow Scroll right and display more menu items or move cursor
one character to the right

Up arrow Exit screen and go up one level

Small down Move cursor down the list of options or display more items
arrow below
Small up arrow Move cursor up the list of items or display more items
above
Left arrow Move cursor one character to the left

Plus sign Increase the highlighted value or show the next item in the
list.
Minus sign Show the previous item in the list

When you reach the last screen, press the right arrow again to cycle through the
screen menus.

Meter screen menus overview

All meter screens are grouped logically, according to their function.

32 HRB1684301-12
Display PowerLogic™ PM5500 / PM5600 / PM5700 series

You can access any available meter screen by first selecting the Level 1 (top level)
screen that contains it.

Level 1 screen menus - IEEE title [IEC title]

Amps [I] Volts [U-V] Harm Power [PQS] Energy [E] PF Hz [F]

THD Unbal MnMx Alarm I/O Timer QR Maint Clock

Menu tree
Use the menu tree to navigate to the setting you want to view or configure.
The image below summarizes the available meter screens (IEEE menus shown,
with the corresponding IEC menus in parentheses).
Level 1 Level 2 Level 3 Level 1 Level 2 Level 3
Amps
Phase MnMx Amps [I]
[I]
Dmd Iavg Ia [I1] Ib [I2] Ic [I3] In Ig Volts [U-V] V L-L [U] V L-N [V]
Ig Power [PQS] Active [P] Reac [Q] Appr [S]
RCM (PM5660 / PM5661 / PM5760 / PM5761 only) PF True Disp
Volts Hz [F]
V L-L [U]
[U-V] THD thd
V L-N [V] THD
Unbal Amps [I] V L-L [U] V L-N [V]
Harm V L-L [U] Fund 3-11 13-21 23-31 QR
V L-N [V] Fund 3-11 13-21 23-31
Fund 3-11 13-21 23-31 Alarm Active
Amps [I]
TDD / K Hist

Crest Amps [I] V L-L [U] V L-N [V] Count

Unack
Power
Power [PQS]
[PQS] QR
Phase Active [P] Reac [Q] Appr [S]
Wd [Pd] Tot A [1] B [2] C [3] I/O D Out D1 D2
Dmd
VARd [Qd] Tot A [1] B [2] C [3] D In S1 S2 S3 S4 (S3 & S4: Not applicable in PM5570 / PM5660 / PM5661 / PM5760 / PM5761)
VAd [Sd] A In A1 A2 (PM5570 only)
Tot A [1] B [2] C [3]
QR Timer Load
Energy Oper
Wh
[E]
VAh QR Info Energy Dmd Basic PQ MnMx Alarm Log#1 ..... Log#14
VARh
Tariff T1 T2 T3 T4 T5 T6 T7 T8 Maint Reset Global Resets Single Resets User Acc Resets
Inp Mtr Dmd Ch 1 Ch 2 Ch 3 Ch 4 Setup Meter Basic Advan Dmd Tariff
QR Comm Serial Enet BACnet
PF Alarm 1-Sec Unary Dig Logic Cust1s Dist (Dist: PM5650 / PM5760 / PM5761 only)
True
Disp I/O LED D In D Out Inp Mtr A In (A In: PM5570 only)
Hz HMI Displ Region Vavg Pass (Vavg: Not applicable in PM5561 / PM5562 /
[F] (Frequency) Clock PM5661 / PM5761)
RCM (PM5660 / PM5661 / PM5760 / PM5761 only)
THD THD Amps [I] V L-L [U] V L-N [V] Dist (PM5650 / PM5760 / PM5761 only)
thd Amps [I] V L-L [U] V L-N [V] WFC (PM5650 / PM5760 / PM5761 only)
QR
Diag Info
Unbal (Unbalance) Meter
Clock Cl Pwr
Phasor Polar
QR

Lock (PM5561 / PM5661 / PM5761 only)

Clock (Clock parameters)

Data display screens

The meter display screens allow you to view meter values and configure settings.
The titles listed are for the HMI mode in IEEE, with the corresponding titles in IEC
mode in square brackets [ ].
• Bulleted items indicate subscreens and their descriptions.

Amps [I]

Phase Instantaneous current measurements for each phase and neutral (Ia [I1], Ib [I2], Ic [I3], In).

Dmd Summary of peak current demand values at the last demand interval for each phase and neutral
(Ia [I1], Ib [I2], Ic [I3], In).

• Iavg, Ia [I1], Ib [I2], Ic [I3], In, Ig • Real-time demand (Pres), peak demand (Peak) and predicted demand (Pred) for the
present interval. Average demand for the previous (Last) interval.

• Pk DT • Date and timestamp for the peak demand readings.

Ig Average (Iavg), neutral (In) and residual/ground (Ig) current.

RCM (PM5660 / PM5661 / PM5760 / Instantaneous residual current measurement (I5 and I6).
PM5761 only)

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PowerLogic™ PM5500 / PM5600 / PM5700 series Display

Volts [U-V]

V L-L [U] Line-to-line phase voltage (Vab [U12], Vbc [U23], Vca [U31]).

V L-N [V] Line-to-neutral phase voltage (Van [V1], Vbn [V2]), Vcn [V3]).

Harm

V L-L [U] Line-to-line voltage harmonics data: Numeric magnitude and angle for the fundamental
• Fundamental, 3-11, 13-21, 23-31 harmonic, and graphical representation of harmonics for the 3rd to 11th, 13th to 21st, and 23rd
to 31st odd harmonics for each line-to-line phase voltage (Vab [U12], Vbc [U23], Vca [U31]).

V L-N [V] Line-to-neutral voltage harmonics data: Numeric magnitude and angle for the fundamental
• Fundamental, 3-11, 13-21, 23-31 harmonic, and graphical representation of harmonics for the 3rd to 11th, 13th to 21st, and 23rd
to 31st odd harmonics for each line-to-neutral phase voltage (Van [V1], Vbn [V2]), Vcn [V3]).

Amps [I] Current harmonics data: Numeric magnitude and angle for the fundamental harmonics, and
• Fundamental, 3-11, 13-21, 23-31 graphical representation of harmonics for the 3rd to 11th, 13th to 21st, and 23rd to 31st odd
harmonics for each phase current (Ia [I1], Ib [I2], Ic [I3]).

TDD / K Total demand distortion and K-factor data for each phase voltage (K-F A [K-F 1], K-F B [K-F 2],
K-F C [K-F 3]).

Crest Crest factor data for each phase current (Ia [I1], Ib [I2], Ic [I3]), line-to-line phase voltage (Vab
• Amps [I], V L-L [U], V L-N [V] [U12], Vbc [U23], Vca [U31]), and line-to-neutral phase voltage (Van [V1], Vbn [V2]), Vcn [V3]).

Power [PQS]

Power [PQS] Summary of real-time power consumption values for total active power in kW (Total [Ptot]), total
reactive power in kVAR (Total [Qtot]), and total apparent power in kVA (Total [Stot]).

Phase Per phase and total power values for active power in kW (A [P1], B [P2], C [P3], Total [Ptot]),
• Active [P], Reac [Q], Appr [S] reactive power in kVAR (A [Q1], B [Q2], C [Q3], Total [Qtot]) and apparent power in kVA (A [S1],
B [S2], C [S3], Total [Stot]).

Dmd Summary of peak power demand values in the previous (Last) demand interval period for active
power in kW, reactive power in kVAR and apparent power in kVA.

• Wd [Pd], VARd [Qd], VAd [Sd] • Total and per phase peak power demand values in the previous (Last) demand interval for
active power demand (Wd [P]), reactive power demand (VARd [Q]) and apparent power
demand (VAd [S]).

• Tot, A [1], B [2], C [3] • For the selected power demand screen (active, reactive or apparent), each of these sub-
screens (total and per phase demand) display demand values for the present demand
(Pres) interval, predicted demand (Pred) based on the current power consumption rate,
demand for the previous demand (Last) interval period, and recorded peak power demand
(Peak) value.

• Pk DT • Date and timestamp for the peak power demand (Peak) value.

• QR • Power demand parameters embedded in QR code format.

Energy [E]

Wh, VAh, VARh Delivered (Del), received (Rec), delivered plus received (D+R) and delivered minus received (D-
R) accumulated values for active energy (Wh), apparent energy (VAh) and reactive energy
(VARh).

Tariff

• T1, T2, T3, T4, T5, T6, T7, T8 • Displays the available tariffs (T1 through T8).

• Del • Active energy delivered in Wh (W [P]), reactive energy delivered in VARh (VAR [Q]) and
apparent energy delivered in VAh (VA [S]) energy for the selected tariff.

• Rec • Active energy received in Wh (W [P]), reactive energy received in VARh (VAR [Q]) and
apparent energy received in VAh (VA [S]) energy for the selected tariff

• InMet • Accumulated values on the input metering channels (Ch 1 to Ch 4) for the selected tariff.

Inp Mtr Accumulated values on the input metering channels (Ch 1 to Ch 4).

• Dmd • Summary of demand values for input metering channels Ch 1 to Ch 4 in the previous
(Last) demand interval.

• Ch 1, Ch 2, Ch 3, Ch 4 • Demand values for present (Pres) and previous (Last) interval periods, predicted demand
(Pred) based on the current consumption rate, and recorded peak demand (Peak) value
for the selected input metering channel.

34 HRB1684301-12
Display PowerLogic™ PM5500 / PM5600 / PM5700 series

Energy [E] (Continued)

• Pk DT • Date and timestamp for the peak demand reading.

QR Energy parameters (Wh, VAh, VARh, Tariff and Input metering) embedded in QR code format.

PF

True True power factor values per phase and total (PFa [PF1], PFb [PF2], PFc [PF3], Total [Ptot]), PF
sign, and load type (capacitive = lead, inductive = lag).

Disp Displacement power factor values per phase and total (PFa [PF1], PFb [PF2], PFc [PF3], Total
[Ptot]), PF sign, and load type (capacitive = lead, inductive = lag).

Hz [F]

Frequency (Freq). This page also displays average voltage (Vavg), average current (Iavg) and total power factor (PF) values.

THD

THD THD (ratio of harmonic content to the fundamental) for phase currents (Ia [I1], Ib [I2], Ic [I3], In),
• Amps [I], V L-L [U], V L-N [V] line-to-line voltages(Vab [U12], Vbc [U23], Vca [U31]) and line-to-neutral voltages (Van [V1], Vbn
[V2], Vcn [V3]).

thd thd (ratio of harmonic content to the rms value of total harmonic content) phase currents (Ia [I1],
• Amps [I], V L-L [U], V L-N [V] Ib [I2], Ic [I3], In), line-to-line voltages(Vab [U12], Vbc [U23], Vca [U31]) and line-to-neutral
voltages (Van [V1], Vbn [V2], Vcn [V3]).

QR Power quality parameters (THD and thd) embedded in QR code format.

Unbal

Percent unbalance readings for line-to-line voltage (V L-L [U]), line-to-neutral voltage (V L-N [V]) and current (Amps [I]).

MnMx

Amps [I] Summary of minimum and maximum values for phase current.

Volts [U-V] Summary of minimum and maximum values for line-to-line voltage and line-to-neutral voltage.
• V L-L [U], V L-N [V]

Power [PQS] Minimum and maximum values for active, reactive, and apparent power.
• Active [P], Reac [Q], Appr [S]

PF Minimum and maximum values for true and displacement PF and PF sign.
• True, Disp

Hz [F] Minimum and maximum values for frequency.

THD

• THD, thd Minimum and maximum values for total harmonic distortion (THD or thd).

◦ Amps [I], V L-L [U], V L-N • THD or thd minimum and maximum values for phase or neutral current, line-to-line voltage
[V] and line-to-neutral voltage.

Unbal Minimum and maximum values for current unbalance, line-to-line voltage unbalance and line-to-
• Amps [I], V L-L [U], V L-N [V] neutral voltage unbalance.

QR Minimum and maximum values (phase current, line-to-line voltage, line-to-neutral voltage,
power (PQS), PF, frequency, power quality and Unbal) embedded in QR code format.

Alarm

Active, Hist, Count, Unack Lists all active alarms (Active), past alarms (Hist), the total number of times each standard alarm
was tripped (Count), and all unacknowledged alarms (Unack).

QR Alarm parameters (active, past alarms, the total number of times each standard alarm was
tripped, unacknowledged) embedded in QR code format.

HRB1684301-12 35
PowerLogic™ PM5500 / PM5600 / PM5700 series Display

I/O

D Out Current status (on or off) of the selected digital output or digital input. Counter shows the total
number of times an off-to-on change of state is detected. Timer shows the total time (in seconds)
• D1, D2
that a digital input or digital output is in the on state.
D In
• S1, S2, S3, S4

A In (PM5570 only) Summary of analog inputs (A1 & A2).

• A1, A2 • Raw Value (mA)
• Scaled Value
• Unit

Timer

Load Real-time counter that keeps track of the total number of days, hours, minutes and seconds an
active load is connected to the meter inputs.

Oper Real-time counter for the total number of days, hours, minutes and seconds the meter has been
powered.

QR

Meter info details, energy parameters, power demand parameters, basic parameter values (current, voltage and power), power quality
parameters, minimum / maximum values (phase current, line-to-line voltage, line-to-neutral voltage, power (PQS), PF, frequency, power
quality and Unbal), alarm parameters and data log parameters embedded in QR code format.

Maint

Resets Screens to perform global resets, single resets and user account resets.
• Global Resets
• Single Resets
• User Acc Resets
Setup

• Meter • Meter configuration screens.

◦ Basic ◦ Screens to define the power system and power system components/elements.

◦ Advan ◦ Screens to set up the active load timer and define the peak demand current for
inclusion in TDD calculations.
◦ Dmd
◦ Screens to set up power demand, current demand and input metering demand.
◦ Tariff
◦ Screens to set up tariffs.

• Comm • Screens to set up serial, Ethernet and BACnet communications.

◦ Serial
◦ Enet
◦ BACnet
• Alarm • Screens to set up standard (1-Sec), unary, digital, logic, custom (Cust1s) and disturbance
◦ 1-Sec alarms.

◦ Unary
◦ Dig
◦ Logic
◦ Cust1s
◦ Dist (PM5650 / PM5760 /
PM5761 only)

• I/O • Screens to set up the alarm / energy pulsing LED, digital inputs/outputs, input metering
◦ LED channels and analog inputs.

◦ D In
◦ D Out
◦ Inp Mtr
◦ A In (PM5570 only)

• HMI • Screens to configure display settings, edit regional settings, select the type of average
◦ Displ voltage you want the meter to display on the summary page and set up meter display
access passcodes.
◦ Region

36 HRB1684301-12
Display PowerLogic™ PM5500 / PM5600 / PM5700 series

Maint (Continued)

◦ Vavg (Not applicable in

PM5561 / PM5562 / PM5661
/ PM5761)
◦ Pass
• Clock • Screens to set up the meter date and time.

• RCM (PM5660 / PM5661 / • Screen to set up I5 toroid and I6 toroid turns.

PM5760 / PM5761 only)

• Dist (PM5650 / PM5760 / • Screen to set up sag and swell limits.

PM5761 only)

• WFC (PM5650 / PM5760 / • Screen to set up waveform capture.

PM5761 only)

Diag Diagnostic screens provide meter information for troubleshooting.

• Info • The Info screen displays the meter model, serial number, date of manufacture, firmware
version (including OS - Operating System and RS - Reset System), language version, and
OS CRC (Cyclic Redundancy Check). The OS CRC value is a number (Hexadecimal
format) that identifies the uniqueness between different OS firmware versions.

• Meter • Displays the meter status.

• Cl Pwr • Non-MID meter models: The Cl Pwr screen displays how many times the meter lost
control power, and the date and time of its last occurrence.
• MID meter models: The Cl Pwr screen displays how many times the meter lost control
power (auxiliary power), and the last power up and power down events with the timestamp.

• Phasor • Displays a graphical representation of the power system the meter is monitoring.
◦ Polar ◦ Displays the numeric magnitude and angles of all voltage and current phases.

• QR • Meter info details embedded in QR code format.

Lock (PM5561 / PM5661 / PM5761 This locks or unlocks the MID protected quantities.
only)

Clock

Meter date and time (local or GMT).

HMI setup screens

You can configure the meter’s display using the HMI setup screens.
The HMI (human-machine interface) setup screens allow you to:
• control the general appearance and behavior of the display screens,
• change the regional settings,
• select the type of average voltage you want the meter to display on the
summary page (Not applicable in PM5561 / PM5562 / PM5661 / PM5761
meter models),
• change the meter passcodes,
• enable or disable the QR code feature for accessing meter data.
See the Meter Insights QR code feature quick start guide for more information on
accessing meter data using QR codes.

Setting up the display

You can change the display screen’s settings, such as contrast, display and
backlight timeout and QR code display.
1. Navigate to Maint > Setup.
2. Enter the setup passcode (default is “0”), then press OK.

HRB1684301-12 37
PowerLogic™ PM5500 / PM5600 / PM5700 series Display

3. Navigate to HMI > Displ.

4. Move the cursor to point to the parameter you want to modify, then press
Edit.
5. Modify the parameter as required, then press OK.
6. Move the cursor to point to the next parameter you want to modify, press Edit,
make your changes, then press OK.
7. Press the up arrow to exit.
8. Press Yes to save your changes.

Display settings available using the display

Parameter Values Description

Contrast 1-9 Increase or decrease the value to increase or decrease the display contrast.

Bcklght Timeout (min) 0 - 99 Set how long (in minutes) before the backlight turns off after a period of inactivity.
Setting this to “0” disables the backlight timeout feature (i.e., backlight is always
on).

Screen Timeout (min) 0 - 99 Set how long (in minutes) before the screen turns off after a period of inactivity.
Setting this to “0” disables the screen timeout feature (i.e., display is always on).

QR Code Enable, Disable Set whether or not QR codes with embedded data are available on the display.

See the Meter Insights QR code feature quick start guide for more information
on accessing meter data using QR codes.
To configure the display using ION Setup, see the section for your meter in
the ION Setup online help or in the ION Setup device configuration guide,
available for download at www.se.com.

Setting up the average voltage (Vavg) on the summary page using

the display
Not applicable in PM5561 / PM5562 / PM5661 / PM5761 meter models.
You can select the type of average voltage you want the meter to display on the
summary page.
1. Navigate to Maint > Setup.
2. Enter the setup passcode (default is “0”), then press OK.
3. Navigate to HMI > Vavg.
4. Move the cursor to point to Vavg you want to modify, then press Edit.
5. Select the parameter (Auto / Voltage L-L / Voltage L-N) as required, then
press OK.

38 HRB1684301-12
Display PowerLogic™ PM5500 / PM5600 / PM5700 series

6. Press the up arrow to exit. Press Yes to save your changes.

Average voltage (Vavg) settings available using the display

Parameter Values Description

Auto Factory default setting Vavg on Summary page will show average line-to-line or line-to-neutral voltage
based on the wiring configuration.

Voltage L-L Max 690 V L-L If the selected wiring configuration does not have line-to-line voltage to be
measured, the Vavg parameter on the Summary page will show a sequence of
asterisks (*****).

Voltage L-N Max 400 V L-N If the selected wiring configuration does not have line-to-neutral voltage to be
measured, the Vavg parameter on the Summary page will show a sequence of
asterisks (*****).

NOTE: Change in setting will only affect the average voltage value
displayed on the Summary page of the meter. The average voltage value
displayed on the Frequency (Hz or F) page and encoded into the QR
code is always based on Auto mode.

HRB1684301-12 39
PowerLogic™ PM5500 / PM5600 / PM5700 series Basic setup

Basic setup
Configuring basic setup parameters using the display
You can configure basic meter parameters using the display.
Proper configuration of the meter’s basic setup parameters is essential for
accurate measurement and calculations. Use the Basic Setup screen to define the
electrical power system that the meter is monitoring.
If standard (1-sec) alarms have been configured and you make subsequent
changes to the meter’s basic setup, all alarms are disabled to prevent undesired
alarm operation.

NOTICE
UNINTENDED EQUIPMENT OPERATION
• Verify all standard alarms settings are correct and make adjustments as
necessary.
• Re-enable all configured alarms.
Failure to follow these instructions can result in equipment damage.

After saving the changes, confirm all configured standard alarm settings are still
valid, reconfigure them as required, and re-enable the alarms.
1. Navigate to Maint > Setup.
2. Enter the setup passcode (default is “0”), then press OK.
3. Navigate to Meter > Basic.
4. Move the cursor to point to the parameter you want to modify, then press
Edit.
5. Modify the parameter as required, then press OK.
6. Move the cursor to point to the next parameter you want to modify, press Edit,
make your changes, then press OK.

40 HRB1684301-12
Basic setup PowerLogic™ PM5500 / PM5600 / PM5700 series

7. Press Yes to save your changes.

Basic setup parameters available using the display

Values Description

Power System

Select the power system type (power transformer) the meter is wired to.

1PH2W LN Single-phase 2-wire line-to-neutral

1PH2W LL Single-phase 2-wire line-to-line

1PH3W LL with N Single-phase 3-wire line-to-line with neutral

3PH3W Dlt Ungnd 3-phase 3-wire ungrounded delta

3PH3W Dlt Crnr Gnd 3-phase 3-wire corner grounded delta

3PH3W Wye Ungnd 3-phase 3-wire ungrounded wye

3PH3W Wye Gnd 3-phase 3-wire grounded wye

3PH3W Wye Res Gnd 3-phase 3-wire resistance-grounded wye

3PH4W Opn Dlt Ctr Tp 3-phase 4-wire center-tapped open delta

3PH4W Dlt Ctr Tp 3-phase 4-wire center-tapped delta

3PH4W Wye Ungnd 3-phase 4-wire ungrounded wye

3PH4W Wye Gnd 3-phase 4-wire grounded wye

3PH4W Wye Res Gnd 3-phase 4-wire resistance-grounded wye

VT Connect
Select how many voltage transformers (VT) are connected to the electrical power system.

Direct Con Direct connect; no VTs used

2VT 2 voltage transformers

3VT 3 voltage transformers

VT Primary (V)

1 to 1,000,000 Enter the size of the VT primary, in Volts.

VT Secondary (V)

100, 110, 115, 120 Select the size of the VT secondary, in Volts.

CT on Terminal
Define how many current transformers (CT) are connected to the meter, and which terminals they are connected to.

I1 1 CT connected to I1 terminal
I2 1 CT connected to I2 terminal
I3 1 CT connected to I3 terminal
I1 I2 2 CT connected to I1, I2 terminals

I1 I3 2 CT connected to I1, I3 terminals

I2 I3 2 CT connected to I2, I3 terminals

I1 I2 I3 3 CT connected to I1, I2, I3 terminals

I1 I2 I3 IN 4 CT connected to I1, I2, I3, IN terminals

CT Primary (A)

1 to 32767 Enter the size of the CT primary, in Amps.

CT Secondary (A)

1, 5 Select the size of the CT secondary, in Amps.

CT Primary Neu. (A)

1 to 32767 This parameter displays when CT on Terminal is set to I1,I2,I3, IN. Enter the size of the 4th
(Neutral) CT primary, in Amps.

HRB1684301-12 41
PowerLogic™ PM5500 / PM5600 / PM5700 series Basic setup

Basic setup parameters available using the display (Continued)

Values Description

CT Sec. Neu. (A)

1, 5 This parameter displays when CT on Terminal is set to I1,I2,I3, IN. Select the size of the 4th
(Neutral) CT secondary, in Amps.

Sys Frequency (Hz)

50, 60 Select the frequency of the electrical power system, in Hz.

Phase Rotation
ABC, CBA Select the phase rotation of the 3-phase system.

Configuring advanced setup parameters using the display

You can configure a subset of advanced parameters using the display.
1. Navigate to Maint > Setup.
2. Enter the setup passcode (default is “0”), then press OK.
3. Navigate to Meter > Advan.
4. Move the cursor to point to the parameter you want to modify, then press
Edit.
5. Modify the parameter as required, then press OK.
6. Move the cursor to point to the next parameter you want to modify, press Edit,
make your changes, then press OK.
7. Press Yes to save your changes.

Advanced setup parameters available using the display

Parameter Values Description

Label — This label identifies the device, e.g., “Power Meter”. You cannot use the display to
edit this parameter. Use ION Setup to change the device label.

Load Timer Setpt (A) 0 - 18 Specifies the minimum average current at the load before the timer starts. The
meter begins counting the number of seconds the load timer is on (i.e., whenever
the readings are equal to or above this average current threshold.

Pk I dmd for TDD (A) 0 - 18 Specifies the minimum peak current demand at the load for inclusion in total
demand distortion (TDD) calculations. If the load current is below the minimum
peak current demand threshold, the meter does not use the readings to calculate
TDD. Set this to “0” (zero) if you want the power meter to use the metered peak
current demand for this calculation.

Setting up regional settings

You can change the regional settings to localize the meter screens and display
data in a different language, using local standards and conventions.
NOTE: In order to display a different language other than those listed in the
Language setup parameter, you need to download the appropriate language
file to the meter using the firmware upgrade process.
1. Navigate to Maint > Setup.
2. Enter the setup passcode (default is “0”), then press OK.
3. Navigate to HMI > Region.
4. Move the cursor to point to the parameter you want to modify, then press
Edit.

42 HRB1684301-12
Basic setup PowerLogic™ PM5500 / PM5600 / PM5700 series

5. Modify the parameter as required, then press OK.

6. Move the cursor to point to the next parameter you want to modify, press Edit,
make your changes, then press OK.
7. Press the up arrow to exit.
8. Press Yes to save your changes.

Regional settings available using the display

Parameter Values Description

Language English US, Select the language you want the meter to display.
French,
Spanish,
German, Italian,
Portuguese,
Chinese,
Russian
Date Format MM/DD/YY, YY/ Set how you want the date to be displayed, e.g., month/
MM/DD, DD/ day/year.
MM/YY
Time Format 24Hr, AM/PM Set how you want the time to be displayed, e.g.,
17:00:00 or 5:00:00 PM.
HMI Mode IEC, IEEE Select the standards convention used to display menu
names or meter data.

Resetting the display language

To reset the meter to the default language (English), press and hold the outermost
two buttons for 5 seconds.

Setting up the screen passcodes

It is recommended that you change the default passcode in order to prevent
unauthorized personnel from accessing passcode-protected screens such as the
diagnostics and reset screens.
This can only be configured through the front panel. The factory-default setting for
all passcodes is “0000” (zero).
If you lose your passcode, contact Schneider Electric technical support for
assistance.

NOTICE
IRRECOVERABLE PASSCODE
Record your device's user and passcode information in a secure location.
Failure to follow these instructions can result in data loss.

NOTICE
LOSS OF DATA OR PRODUCT CONFIGURATION
Do not let unauthorized personnel gain physical access to the device.
Failure to follow these instructions can result in data loss and loss of
access to the device.

1. Navigate to Maint > Setup.

2. Enter the setup passcode (default is “0”), then press OK.
3. Navigate to HMI > Pass.

HRB1684301-12 43
PowerLogic™ PM5500 / PM5600 / PM5700 series Basic setup

4. Move the cursor to point to the parameter you want to modify, then press
Edit.

Parameter Values Description

Setup 0000 - 9999 Sets the passcode for accessing the meter setup screens (Maint > Setup).

Energy Resets 0000 - 9999 Sets the passcode for resetting the meter’s accumulated energy values.

Demand Resets 0000 - 9999 Sets the passcode for resetting the meter’s recorded peak demand values.

Min/Max Resets 0000 - 9999 Sets the passcode for resetting the meter’s recorded minimum and maximum
values.
User Acc Resets 0000 - 9999 Sets the passcode for resetting the meter’s user accounts.

5. Modify the parameter as required, then press OK.

6. Move the cursor to point to the next parameter you want to modify, press Edit,
make your changes, then press OK.
7. Press the up arrow to exit.
8. Press Yes to save your changes.

PM5RD device hardware version Ax/Bx support for PM5563 and

PM5563RD meter models
The PM5RD device may have one of the following two Hardware (H/W) versions:
• H/W : Ax
• H/W : Bx
(x = number)
The PM5563 meter with firmware version older than 2.7.4 supports PM5RD
device H/W version Ax only.
The PM5563 and PM5563RD meter models with firmware version 2.7.4 and
above (factory-shipped or field-upgraded) supports PM5RD device H/W version
Ax or Bx, if the meter is configured accordingly:
• PM5563 meter without PM5RD device: You need not make any changes to
the configuration.
• PM5563 meter connected to PM5RD device and the setup is already
working: You need not make any changes to the configuration. This is
applicable even after you upgrade the PM5563 meter in this setup from an
older firmware version to 2.7.4 and above.
• PM5563RD meter: The PM5RD device works with PM5563 meter that is
available in the box without the need of any additional configuration for
display.
• PM5563 meter with a separately purchased PM5RD device: You must
follow the below instructions Configuring PM5563 meter for PM5RD device
hardware version to configure.

Configuring PM5563 meter for PM5RD device hardware version

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.

44 HRB1684301-12
Basic setup PowerLogic™ PM5500 / PM5600 / PM5700 series

1. Connect the PM5RD device to PM5563 meter and power-on the meter.
NOTE: If the PM5RD device is operating normally, then the instructions in
this section are not applicable until you choose to change the connected
PM5RD device to another PM5563 meter. If the connected PM5RD
device does not display any content with backlight on, then proceed to
next step.
2. Open web browser and enter the meter’s IP address in the address box.
3. Enter the Username and Password.
4. Based on your meter firmware version, click Diagnostics > Meter
Information OR click Home > Device Identification.
If the firmware version is lower than 2.7.4, proceed to Step 5. If the firmware
version is 2.7.4 and above, proceed to Step 6.
5. Refer to Firmware upgrades, page 200 section under chapter Maintenance to
upgrade PM5563 meter to latest firmware version (2.7.4 and above).
6. Based on the meter model and firmware version, click Settings > PM55x3RD
Remote Display OR click Settings > Communication > PM55x3RD
Remote Display.
The PM55x3RD Display Settings window opens.
The default value displayed in the drop-down field indicates the current
hardware version setting for the connected PM5RD device. The hardware
version information can be found on the label on back side of the PM5RD
device. If you need to change the hardware version setting, proceed to next
step.

7. Select the appropriate hardware version setting from the drop-down list.
8. After you select the hardware version setting, a warning message displays.
Make sure that you read and understand the message. Select OK to proceed
or Cancel to retain the existing setting.
9. After the new hardware version setting is selected, select Save changes or
Apply Changes. Another warning message displays.
Make sure that you read, understand and follow the instructions to reduce
chances of abnormal operation. Select OK to proceed or Cancel to abort
saving changes.

HRB1684301-12 45
PowerLogic™ PM5500 / PM5600 / PM5700 series Basic setup

10. Select OK to see the new setting on the webpage.

11. Restart the meter for saved changes to take effect, even if display is working
after the H/W type change.

Configuring toroid settings for RCM using the display

Applicable only in PM5660 / PM5661 / PM5760 / PM5761 meter models.
You can configure toroid settings for RCM using the display.
1. Navigate to Maint > Setup.
2. Enter the setup passcode (default is “0”), then press OK.
3. Navigate to RCM.
4. Select I5 Toroid (Turns) or I6 Toroid (Turns) , then press Edit.
NOTE: The default toroid turns setting for I5 and I6 is 1000. The I5 Toroid
(Turns) and I6 Toroid (Turns) can be set from 300 to 3000.
5. Modify the parameters as required, then press OK.

Toroid turns setting example

Toroid Turns Residual current Measured residual current meets specified Primary current through
measurement starts at accuracy sensor not to exceed
(mA) (1.5 X Toroid turns) (mA)
From To
(0.005 X Toroid turns)* (1.2 X Toroid turns)
(mA) (mA)

300 5 360 450

600 5 720 900
1000 (Default) 5 1200 1500
3
1500 7.5 1800 2250
2500 12.5 3000 3750
3000 15 3600 4500
* For toroid sensors with turns less than 1000, the formula is not applicable - measured residual current meets specified accuracy starting
from 5 mA.

46 HRB1684301-12
Cybersecurity PowerLogic™ PM5500 / PM5600 / PM5700 series

Cybersecurity
Cybersecurity overview
This chapter contains information about your product’s cybersecurity. Network
administrators, system integrators and personnel that commission, maintain or
dispose of a device should:
• Apply and maintain the device’s security capabilities. See “Device security
capabilities”, page 48 for details.
• Review assumptions about protected environments. See "Protected
environment assumptions", page 49 for details.
• Address potential risks and mitigation strategies. See “Potential Risks and
compensating controls”, page 49 for details.
• Follow recommendations to optimize cybersecurity.
Your device has security capabilities that:
• Allow it to be part of a NERC CIP compliant facility. Go to the North American
Electric Reliability Corporation website for information on NERC Reliability
Standards.
• Align with cybersecurity standards in the IEC 62443 international standard for
business IT systems and Industrial Automation and Control Systems (IACS)
products. Go to the International Electrotechnical Commission website for
information about the IEC 62443 international standard.
Meters manufactured on and after 1-January-2020 comply with Senate Bill 327 or
SB-327 of California connected devices, effective in the state of California from
beginning of the year 2020. Go to the https://leginfo.legislature.ca.gov/faces/
billTextClient.xhtml?bill_id=201720180SB327 website for information about the
bill.
To communicate a security topic affecting a Schneider Electric product or solution,
go to http://www.se.com/en/work/support/cybersecurity/vulnerability-policy.jsp.

WARNING
POTENTIAL COMPROMISE OF SYSTEM AVAILABILITY, INTEGRITY, AND
CONFIDENTIALITY
• Change default passwords/passcodes to help prevent unauthorized access
to device settings and information.
• Disable unused ports/services and default accounts, where possible, to
minimize pathways for malicious attacks.
• Place networked devices behind multiple layers of cyber defenses (such as
firewalls, network segmentation, and network intrusion detection and
protection).
• Use cybersecurity best practices (for example: least privilege, separation of
duties) to help prevent unauthorized exposure, loss, modification of data and
logs, interruption of services, or unintended operation.
Failure to follow these instructions can result in death, serious injury, or
equipment damage.

Product defense-in-depth
Use a layered network approach with multiple security and defense controls in
your IT and control system to minimize data protection gaps, reduce single-point-
of-failure and create a strong cybersecurity posture. The more layers of security in
your network, the harder it is to breach defenses, take digital assets or cause
disruption.

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Device security capabilities

This section describes the security capabilities available with your device.

Information confidentiality
These security capabilities help protect the confidentiality of information through
secure protocols that help prevent unauthorized users from reading information in
transit.

Physical security
These security capabilities together with perimeter security help prevent
unauthorized access to revenue-related parameters and settings or leave clear
evidence that the device has been physically tampered with:
• Physical revenue-lock switch on the meter is used to help prevent
unauthorized access to the meter, parameter values and settings.
• Meter lock status indicators are used to determine if the meter is revenue
locked, i.e. LED lock status indicator on device and revenue lock icon on the
display.
• Multiple anti-tamper sealing points are used to help prevent access and
leaves evidence of tampering.
See “Revenue locking”, page 216 for details about physically locking and sealing
the device.

Configuration
These security capabilities support the analysis of security events, help protect the
device from unauthorized alteration and records configuration changes and user
account events:
• Internal time synchronization.
• Meter configuration event logging.
• Timestamps, including date and time, match the meter clock.
• Internal FTP site to store files in the meter’s flash memory, such as:
webpages, COMTRADE records and firmware files.

User accounts
These security capabilities help enforce authorizations assigned to users,
segregation of duties and least privilege:
• User authentication is used to identify and authenticate software processes
and devices managing accounts.
• Least privilege configurable in multiple dimensions: read, peak demand reset,
time sync, test mode, meter configuration and security communications
configuration.
• User account lockout with 5 unsuccessful login attempts.
• Administrators can override user authorizations by deleting their account.

Hardening
These security capabilities help prohibit and restrict the use of unnecessary
functions, protocols and/or services:
• Least functionality can be applied to prohibit and restrict the use of
unnecessary functions, protocols and/or services.
• Port numbers can be changed from default values to lower the predictability
of port use.

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• Terminating user account sessions in webages.

Protected environment assumptions

• Cybersecurity governance – available and up-to-date guidance on governing
the use of information and technology assets in your company.
• Perimeter security – installed devices, and devices that are not in service, are
in an access-controlled or monitored location.
• Emergency power – the control system provides the capability to switch to
and from an emergency power supply without affecting the existing security
state or a documented degraded mode.
• Firmware upgrades – meter upgrades are implemented consistently to the
current version of firmware.
• Controls against malware – detection, prevention and recovery controls to
help protect against malware are implemented and combined with
appropriate user awareness.
• Physical network segmentation – the control system provides the capability
to:
◦ Physically segment control system networks from non-control system
networks.
◦ Physically segment critical control system networks from non-critical
control system networks.
• Logical isolation of critical networks – the control system provides the
capability to logically and physically isolate critical control system networks
from non-critical control system networks. For example, using VLANs.
• Independence from non-control system networks – the control system
provides network services to control system networks, critical or non-critical,
without a connection to non-control system networks.
• Encrypt protocol transmissions over all external connections using an
encrypted tunnel, TLS wrapper or a similar solution.
• Zone boundary protection – the control system provides the capability to:
◦ Manage connections through managed interfaces consisting of
appropriate boundary protection devices, such as: proxies, gateways,
routers, firewalls and encrypted tunnels.
◦ Use an effective architecture, for example, firewalls protecting application
gateways residing in a DMZ.
◦ Control system boundary protections at any designated alternate
processing sites should provide the same levels of protection as that of the
primary site, for example, data centers.
• No public internet connectivity – access from the control system to the
internet is not recommended. If a remote site connection is needed, for
example, encrypt protocol transmissions.
• Resource availability and redundancy – ability to break the connections
between different network segments or use duplicate devices in response to
an incident.
• Manage communication loads – the control system provides the capability to
manage communication loads to mitigate the effects of information flooding
types of DoS (Denial of Service) events.
• Control system backup – available and up-to-date backups for recovery from
a control system failure.

Potential risks and compensating controls

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
Address potential risks using these compensating controls:

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Area Issue Risk Compensating controls

User accounts Default account settings are If you do not change the default Change the default password to
often the source of unauthorized password, unauthorized access help reduce unauthorized
access by malicious users. can occur. access.

Secure protocols Modbus TCP/IP, EtherNet/IP, If a malicious user gained For transmitting data over an
BACnet/IP, FTP, HTTP, SNMP, access to your network, they internal network, physically or
SNTP, SMTP and DNP3 could intercept communications. logically segment the network.
protocols are unsecure.
For transmitting data over an
The device does not have the external network, encrypt
capability to transmit encrypted protocol transmissions over all
data using these protocols. external connections using an
encrypted tunnel, TLS wrapper
or a similar solution.

Default settings
NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.

Area Setting Default

Communication Modbus TCP/IP Enabled

protocols
EtherNet/IP Enabled
BACnet/IP Enabled
FTP / FTPS* Disabled
SNMP Enabled
SNTP Disabled
SMTP Disabled
DNP3 Disabled
HTTP / HTTPS* Enabled
Time and time keeping Time synchronization Disabled

Web browser Webpages Enabled

Configuration Using the Display Enabled

Using webpages Enabled

Using Modbus programming Enabled

* Available only in latest firmware versions:

• PM5560 / PM5562 / PM5563 / PM5580 meter models: 4.0.0 and above
• PM5570 / PM5660 / PM5760 meter models: 6.0.0 and above
• PM5650 meter model: 4.10.0 and above
• PM5561 meter model: 12.0.0 and above
• PM5661 / PM5761 meter models: 14.0.0 and above

User accounts and permissions

Recommendations to optimize cybersecurity in a protected environment:
• Assign users only the essential permissions needed to perform their role.
• Revoke user permissions when no longer needed due to role change,
transfer or termination.
• Follow user account management tasks as described by your organization or
contact your network administrator.

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User account lockout policy

After the 5th consecutive invalid login attempt, the webpage login is locked for 2
minutes. After 2 minutes (expiry), the webpage is unlocked.

Passwords/Passcodes
NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
Recommendations to optimize cybersecurity in a protected environment:
• Document and store passwords and usernames in a protected location.
• Change the default password/passcode to help reduce unauthorized access.
Default account settings are often the source of unauthorized access by
malicious users.
• Use complex passwords or passphrases with a minimum length of six
characters.
• Follow user account management tasks as described by your organization or
contact your network administrator, for example, maximum password age or
history policies.

Default passwords/passcodes and user accounts

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.

Configuration area Username Default password/passcode

Display passcode — 0000 (zero)

For firmware versions: Webpages and user1 pass1

FTP
• PM5560 / PM5562 / PM5563 / PM5580 user2 pass2
meter models: 2.9.9 and earlier • Web master
• PM5570 / PM5660 / PM5760 meter • Product
models: 3.2.9 and earlier master
• PM5650 meter model: 2.12.9 and earlier
• PM5561 meter model: 10.9.9 and earlier
• PM5661 / PM5761 meter models: 11.2.9
and earlier
For firmware versions: Webpages and Administrator MAC address which is unique for each
FTP/FTPS meter
• PM5560 / PM5562 / PM5563 / PM5580
meter models: 4.0.0 and above NOTE: Enter the MAC address of the
meter without colon in capital letters
• PM5570 / PM5660 / PM5760 meter
models: 6.0.0 and above (For example: if the MAC address of
the meter is 00:80:f4:02:14:38, then
• PM5650 meter model: 4.10.0 and above password is 0080F4021438).
• PM5561 meter model: 12.0.0 and above NOTE: Forced to change the default
• PM5661 / PM5761 meter models: 14.0.0 password for system security the first
and above time you log in.

Webpages Guest Powerlogic@1

NOTE: Forced to change the default
password for system security the first
time you log in.

Changing passwords/passcodes
NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.

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NOTICE
LOSS OF ACCESS
Record your device's user and password/passcode information in a secure
location.
Failure to follow these instructions can result in data loss and loss of
access to the device.

NOTICE
LOSS OF DATA OR PRODUCT CONFIGURATION
Do not let unauthorized personnel gain physical access to the device.
Failure to follow these instructions can result in data loss and loss of
access to the device.

Changing display passcode

See Setting up the screen passcodes, page 43 for instructions on how to change
the default display passcode.

Changing user account passwords

Based on your firmware version, see Configuring user accounts for webpages,
page 59 OR Changing user account password, page 65 for instructions on how to
change the default user account password.

Harden the device

Recommendations to optimize cybersecurity in a protected environment:
• Harden the meter according to your company policies and standards.
• Review assumptions about protected environments and address potential
risks and mitigation strategies. See Product defense-in-depth, page 47 for
details.
• Terminate the user account sessions in webages.
• Change the default passwords/passcodes. See Changing passwords/
passcodes, page 51 for details.
• Change the communication protocol ports from their default values. This
lowers the predictability of port use.
• Disable communication protocol ports when they are not in use. This reduces
the attack surface.

Enabling/Disabling communication protocols and changing port numbers

Changing Ethernet communications using the display

See Setting up Ethernet communications using the display, page 71 for
instructions on how to enable/disable HTTP / HTTPS, DPWS, EtherNet/IP and
DNP3 settings on your meter.

Changing basic Ethernet settings using the webpages

See Configuring basic Ethernet settings using the webpages, page 72 for
instructions on how to change the basic Ethernet settings of your meter.

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Changing advanced Ethernet settings using the webpages

See Configuring advanced Ethernet parameters using the webpages, page 73 for
instructions on how to change the advanced Ethernet settings of your meter.

Changing BACnet/IP settings using the display

See Configuring BACnet/IP settings using the display, page 81 for instructions on
how to change the BACnet/IP settings on your meter.

Changing BACnet/IP settings using the webpages

See Configuring BACnet/IP settings using the webpages, page 82 for instructions
on how to change the BACnet/IP settings of your meter.

Enabling/Disabling DNP3 using the display

See Configuring DNP3 setting using the display, page 112 for instructions on how
to enable/disable DNP3 on your meter.

Enabling/Disabling DNP3 using the webpages

See Configuring DNP3 setting using the webpages, page 113 for instructions on
how to enable/disable DNP3 of your meter.

Enabling/Disabling Modbus TCP/IP filtering using the

webpages
See Configuring Modbus TCP/IP filtering using the webpages, page 117 for
instructions on how to enable/disable Modbus TCP/IP filtering of your meter.

Changing SNMP settings using the webpages

See Configuring SNMP using the webpages, page 120 for instructions on how to
change the SNMP settings of your meter.

Enabling/Disabling FTP / FTPS using the display

See Enabling and disabling the FTP server using the display, page 121 for
instructions on how to enable/disable FTP / FTPS on your meter.

Enabling/Disabling FTP / FTPS using the webpages

See Enabling and disabling the FTP server using the webpages, page 121 for
instructions on how to enable/disable FTP / FTPS of your meter.

Enabling/Disabling the communication protocols and changing

port numbers using the ION Setup
To enable/disable the HTTP / HTTPS, FTP / FTPS, DPWS, SNMP, DNP3,
EtherNet/IP and BACnet/IP communication protocols using ION Setup, see the
section for your meter in the ION Setup online help or in the ION Setup device
configuration guide, available for download at www.se.com.

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Firmware upgrades
When meter firmware is upgraded – security configuration remains the same until
changed, including usernames and passwords/passcodes. It is recommended to
review security configuration after an upgrade to analyze privileges for new or
changed device features and revoke or apply them according to your company
policies and standards.
See Firmware upgrades, page 200 for information about firmware upgrades.

Secure disposal guidelines

Use the Secure disposal checklist when disposing a meter to help prevent
potential disclosure of data.

Secure disposal checklist

• Record activities: Document disposal actions according to your company
policies and standards to keep a record of activities.
• Decommission related rules and sanitize records:
◦ Follow decommission and sanitization tasks as described by your
organization or contact your network administrator.
◦ Decommission network and security rules, e.g. a firewall rule that could be
used to get past the firewall.
◦ Perform records tracking sanitization tasks to remove records in related
systems, e.g. monitoring SNMP servers.
• Disposal and reuse: See Disposal, reuse, recycling, page 54 for more
information.

Disposal, reuse, recycling

Before removing the device from its intended environment, follow the Secure
disposal guidelines in this document.
Follow device removal tasks described by your organization or contact your
network administrator to determine a responsible method of disposal.
Dispose the device according to the legislation of the country. Some regulatory
organizations include:
• The United States Environmental Protection Agency (EPA) for guidance on
the sustainable management of electronics.
◦ The EPA provides an Electronic Product Environmental Assessment Tool
(EPEAT) that helps assess the environmental attributes of electronics.
• The European Waste Electrical & Electronic Equipment Directive (WEEE
Directive) is the community directive on waste electrical and electronic
equipment.
• The European Restriction of Hazardous Substances Directive (RoHS)
directive on the restriction of the use of certain hazardous substances in
electrical and electronic equipment.

NOTICE
UNAUTHORIZED OR UNINTENDED ACCESS TO CONFIDENTIAL DATA
• Store devices that are not in service in an access-controlled or monitored
location.
• Physically destroy devices that are decommissioned.
Failure to follow these instructions can result in unauthorized or
unintended access to sensitive or secure customer data.

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Device disposal
It is recommended that the entire device is physically destroyed. Destroying the
device helps prevent potential disclosure of data contained in the device that was
not removed.
Device reuse
Store the device in a location that is access controlled or monitored if there is
potential for reuse.
Device recycling
Go to www.se.com and search for the Product Environmental Profile for your
meter type to get instructions on managing e-waste.

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Webpages
Webpages (Legacy)
Applicability
This section is only applicable for the meter models and their firmware
versions as shown in the table:

Meter models Firmware version

PM5560 / PM5562 / PM5563 / PM5580 2.9.9 and earlier
PM5570 / PM5660 / PM5760 3.2.9 and earlier
PM5650 2.12.9 and earlier
PM5561 10.9.9 and earlier
PM5661 / PM5761 11.2.9 and earlier

Webpages overview
The meter’s Ethernet connection allows you to access the meter so you can view
data and perform some basic configuration and data export tasks using a web
browser.
The recommended browsers to use for viewing the webpages from the meter are
Microsoft Edge, Google Chrome, Mozilla Firefox, and Apple Safari.

WARNING
INACCURATE DATA RESULTS
• Do not rely solely on data displayed on the display or in software to
determine if this device is functioning correctly or complying with all
applicable standards.
• Do not use data displayed on the display or in software as a substitute for
proper workplace practices or equipment maintenance.
Failure to follow these instructions can result in death, serious injury, or
equipment damage.

Webpages interface
Your meter comes with default webpages.
The graphic below is a representative sample that shows the typical elements.
Your meter’s webpages may appear differently than shown.

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A Meter brand and model D Webpage menu

B Username E Webpage content

C Main menus F Show/hide toggle

Accessing the meter webpages

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
Access the meter’s webpages to view data and perform basic configuration and
data export tasks using a web browser.
The webpages are accessed through the meter’s Ethernet port so it must be
configured properly.
1. Open web browser and enter the meter’s IP address in the address box.
2. Enter your Username and Password.
The Username and Password for the default user accounts are user1 /
pass1 and user2 / pass2.
3. Use the menus and tabs to select and display the meter's various webpages.
4. Click the up / down arrows to show and hide sections of the webpages and
menus.
5. Click Logout to exit the meter webpages.

Default webpages
The meter has a comprehensive set of default webpages that enable you to view
basic energy and power quality values, I/O and alarm information, and data and
maintenance logs.
In addition, you can use the webpages to configure a variety of settings.

Monitoring
This tab allows you to navigate to the following webpages:

Webpage Description

Basic Readings • Basic readings such as Load Current, Power and Voltage in gauge and table display.
• Demand current and demand power values, including last, present and peak.
• Accumulated energy values and the date/time of the last reset.

Residual Current* Displays the instantaneous residual current measurement values.

Power Quality THD and unbalance values for current and voltage.

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Webpage Description

Active Alarms 1 This is a list of active (unacknowledged) alarm events with a date/timestamp for each event, the
value that triggered the alarm (e.g., pickup) and a description of the event type.

Alarm History 1 This is a historical list of (acknowledged) alarm events with a date/timestamp for each event, the
value that triggered the alarm (e.g., pickup) and a description of the event type.

Inputs/Outputs* Displays the current status of the digital inputs/outputs and analog inputs.

Data Log A list of timestamped data recorded in the meter’s data log (energy delivered in Wh, VARh and
VAh).

Waveforms* Displays the waveform capture records caused due to sag/swell events.

*Available in specific meter models. Refer to Features differentiation matrix for PM5500 / PM5600 / PM5700 series, page 20 for the
availability.

Diagnostics
This tab allows you to view the following webpages:

Webpage Description

Meter Information Displays the meter model, serial number and manufacture date in addition to information on the
version numbers of the installed firmware (OS, RS, Ethernet, Language and FPGA)

Communications 2 Contains diagnostics information for Ethernet, HTTP server, HTTP client, Modbus server and
SMTP server to aid in troubleshooting communications.

Displays the meter’s current time and the meter’s last boot time.

Registers Allows you to read a specified block of Modbus registers from the meter or from a slave device
when the meter is acting as a gateway.

Maintenance
This tab allows you to view the Maintenance Log webpage.
The Maintenance Log page displays a record of meter events, and in particular,
changes to meter setup. Each event is date/timestamped. The Event Type field
provides a brief description of what changed and the Event Cause specifies what
triggered the event.

Setting the measurement range for basic parameters

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
You can set the ranges that appear on the gauges that display on the Basic
Readings webpage.
You must login as a web master or product master to change the ranges.
1. Click Set Range.
2. Set the ranges for the gauges:
– Type the minimum and maximum ratings (limits) for current, power and
voltage (L-L and L-N), or
– Set Enable Auto Scale to automatically set the scale on the gauges.
3. Click Save Changes.

1. Click the event number to display additional details about the alarm, for example, the actual pickup or dropout value and which phase the
alarm condition occurred
2. Click Reset to clear the stored information on this page.

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User accounts

Default login accounts

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
The meter has a set of default login credentials to access the webpages and FTP
server.
The following login credentials are configured by default:

Username Password User group

user1 pass1 Web Master

user2 pass2 Product Master

In a continuous effort to encourage users on the awareness about the

cybersecurity best practices and the meters more cyber secure in their
applications, it is recommended for the users to change the default factory-set
password to a complex password.

User groups
NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
Webpages and FTP server access permissions are based on user groups.

User group Access

Web user Users in this group can view all information that is displayed on the webpages.

In addition, a web user can view most device settings available though the webpages (except user
accounts) but cannot change them.

Web master Users in this group can view all information that is displayed on the webpages.

In addition, a web master can change device settings available on the webpages but cannot see or edit
user accounts.
Product master Users in this group can view all information that is displayed on the webpages.

In addition, a product master can change device settings available on the webpages, including user
accounts.

The product master can also access the meter using the FTP server.

Configuring user accounts for webpages

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
You can setup user accounts for access to the meter’s data using the webpages
or FTP, assign users to a group that determines what each user can access, and
set the webpage display language for each user.
You must be logged in as a Product Master to configure user accounts.
NOTE: If you lose your meter’s webpage user access information, contact
Technical Support.
1. Click Settings > User Accounts.
2. Configure the parameters as appropriate for each user.

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3. Click Save changes to send and save the new settings to the meter.

User account settings available using the webpages

Parameter Description

Name Lists the current usernames for accessing the meter. You can add a new user by typing the username
in a blank cell.

To remove an existing user, select the name and press DELETE on your keyboard.

Password 3 Lists the current password associated with each user. After adding a new username, type a password
to associate it with the username. As you enter characters for your password, the status bar changes to
indicate the password strength (weak, medium, strong or very strong). Re-type the password in the
Confirm Password field.
Group Select the group the username belongs to:
• Web User
• Web Master
• Product Master
NOTE: You must have at least one Web Master and one Product Master. User 1 must be a Web
Master and user 2 must be a Product Master.
Language Select the language the webpages are displayed in for the selected username.

Reading device registers using the webpages

You can use the webpages to read a specified block of Modbus registers from the
meter or from a slave device when the meter is acting as a gateway.
1. Navigate to Diagnostics > Registers > Read Device Registers.
2. Type the address of the device you want to read in the Device ID field.
3. Enter values in the Starting Register and Number of Registers fields.
4. Select data format of the registers you want to read from the Data Type field.
5. Select the number format that you want to display the value of the registers in:
Decimal, Hexadecimal, Binary, ASCII or Float.
6. Click Read.
Go to www.se.com and search for your meter’s Modbus register list to
download a copy.

Webpages (New)
Applicability
This section is only applicable for the meter models and their firmware
versions as shown in the table:

Meter models Firmware version

PM5560 / PM5562 / PM5563 / PM5580 4.0.0 and above
PM5570 / PM5660 / PM5760 6.0.0 and above
PM5650 4.10.0 and above
PM5561 12.0.0 and above
PM5661 / PM5761 14.0.0 and above

3. Always record changes or additions to the username and password list and store the list in a safe place.

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Webpages overview
The meter’s Ethernet connection allows you to access the meter so you can view
data and perform some basic configuration and data export tasks using a web
browser.
The recommended browsers to use for viewing the webpages from the meter are
Microsoft Edge, Google Chrome, Mozilla Firefox, and Apple Safari.

WARNING
INACCURATE DATA RESULTS
• Do not rely solely on data displayed on the display or in software to
determine if this device is functioning correctly or complying with all
applicable standards.
• Do not use data displayed on the display or in software as a substitute for
proper workplace practices or equipment maintenance.
Failure to follow these instructions can result in death, serious injury, or
equipment damage.

Webpages interface
Your meter comes with default webpages.
The graphic below is a representative sample that shows the typical elements.
Your meter’s webpages may appear differently than shown.

A Meter brand and model D Webpage menu

B Username E Webpage content

C Main menus

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Accessing the meter webpages

NOTE:
• The webpages are accessed through the meter’s Ethernet port so it must
be configured properly.
• It is mandatory to change the default password when you access the
webpages for the first time. You cannot browse through the webpages
without the default password change.
• The password must contain between 8 and 16 characters with at least 1
number, 1 capital letter and 1 special character.
1. Open a web browser and enter the meter’s IP address in the address box.
2. Enter the Username (default: Administrator) and Password (default: MAC
address which is unique for each meter).
NOTE: Enter the MAC address of the meter without colon in capital letters
(For example: if the MAC address of the meter is 00:80:f4:02:14:38, then
password is 0080F4021438).

WARNING
POTENTIAL COMPROMISE OF SYSTEM AVAILABILITY, INTEGRITY,
AND CONFIDENTIALITY
Recommended to change the default password.
Failure to follow these instructions can result in unauthorized
personnel accessing the web pages.

3. Click Login.
4. Use the menus and tabs to select and display the meter's various webpages.
NOTE: If the user session is inactive for a period of 10 minutes or more,
the session gets timed-out and you need to re-login to access the
webpages.
5. Click Logout to exit the meter webpages.

Default webpages
The meter has a comprehensive set of default webpages that enable you to view
basic energy and power quality values, I/O and alarm information, and data and
maintenance logs.
In addition, you can use the webpages to configure a variety of settings.

Home
This is the default tab when you access the meter webpages. This tab allows you
to view the Device Identification parameters as shown in the following table:

Parameter Description

OEM Name Name of the Original Equipment Manufacturer (OEM)

Schneider Electric
OEM URL URL link of the OEM

www.se.com
Firmware Version Existing firmware version including OS (Operating System), RS
(Reset System), language version and communication card version

FPGA Version Existing FPGA version

Product Range Name of the device type

Product Model Device model number

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Parameter Description

Serial Number Device serial number

Manufacturing Date & Time Date and time when the device was manufactured

Monitoring
This tab allows you to navigate to the following menus to view the webpage
content:

Webpage menu Description

Basic Readings • Basic readings such as load current, power, power factor total, voltage and frequency(Hz).
• Demand current (A) and demand power values, including last, present and peak along with the date
time at peak and date time of the last reset.
• Accumulated energy values and the date time of the last reset.

Residual Current* Displays the instantaneous residual current measurement values.

Power Quality THD and unbalance values for current and voltage.

Active Alarms List of active (unacknowledged) alarm events with the date and timestamp for each event, the value that
triggered the alarm (e.g., pickup) and a description of the event type.
NOTE: You can click the Update button to refresh the active alarms list.

Alarm History Historical list of (acknowledged) alarm events with the date and timestamp for each event, the value that
triggered the alarm (e.g., pickup) and a description of the event type.
NOTE: You can click the Update button to refresh the alarm history list.

Inputs/Outputs* Displays the current status of the digital inputs/outputs and analog inputs.

Data Log A list of timestamps data recorded in the meter’s data log (energy delivered in kWh, kVARh and kVAh).
NOTE: You can click the Update button to refresh the data log list.

Waveforms* Displays the waveform capture records caused due to sag/swell events.

*Available in specific meter models. Refer to Features differentiation matrix for PM5500 / PM5600 / PM5700 series, page 20 for the
availability.

Diagnostics
This tab allows you to view the following webpages:

Webpage menu Webpage submenu Description

General Date/Time Displays the meter’s current date, time and the
meter’s last boot time.
Meter Status Displays the meter diagnostics status.

Communication Ethernet Displays the Ethernet global statistics.

NOTE: You can click the Reset button to reset
the Ethernet global statistics.

IP Network Services Displays the Modbus TCP port and SMTP client
statistics.
NOTE: You can click the Reset button to reset
the Modbus TCP port and SMTP client statistics.

Read Device Registers Allows you to read a specified block of Modbus

registers from the meter or from a slave device when
the meter is acting as a gateway.

Maintenance
This tab allows you to view the following webpages:

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Webpage menu Webpage submenu Description

Maintenance Log Maintenance Log Displays the maintenance log parameters with record
of meter events, and in particular, changes to the
meter setup. Each event is date and timestamped.
The Event Type field provides a brief description of
what changed and the Event Cause specifies what
triggered the event.
NOTE: Click the Update button to refresh the
maintenance log list. You can also click the Next
10 Records or Previous 10 Records to check
the maintenance log records.

Upgrade Firmware Allows you to upgrade firmware for your meter (Refer
to Firmware upgrade using webpages, page 205).

Upgrade Status Displays the last firmware upgrade status of the

meter.

Settings
This tab allows you to view the following webpages:

Webpage menu Webpage submenu Description

Security Product Certificate Displays the product certificate details.

Allows you to create self-signed certificate of the

product.
NOTE: You need to re-login to the webpages to
view the changes applied (create certificate
changes).

Communication Serial Port Configuration Allows you to configure serial port and advanced
serial port settings.

Ethernet Settings Allows you to configure Ethernet settings.

Advanced Ethernet Settings Allows you to configure the advanced Ethernet, FTPS
and HTTPS settings.

Date Time Settings Allows you to configure time synchronization and time
settings manually.

IP Filtering Allows you to set the level of access for each

configured IP address, as well as for anonymous IP
addresses.
NOTE: By default, the Enable Filtering option is
disabled.
DPWS Settings Allows you to enable or disable DPWS.

SNMP Settings Allows you to configure the SNMP and SNMP trap
parameters.

DNP3 Settings Allows you to enable or disable DNP3.

EtherNet/IP Settings Allows you to enable or disable EtherNet/IP.

BACnet/IP Settings Allows you to configure BACnet/IP settings.

Email On Alarm Settings Allows you to configure the Email on alarm settings.

PM55x3RD Remote Display* Allows you to configure PM5563 meter with PM5RD
device hardware version.
User Management User Accounts Allows you to add user accounts, delete user
accounts, reset user account password, assign user
role, and terminate user account sessions.

*Available only in PM5563 meter model.

User accounts
The meter users are assigned with usernames and passwords. Each user is
assigned with a role to access the webpages by the administrator.

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There are two pre-defined user accounts:

• Administrator (default password is MAC address which is unique for each
meter)
NOTE: Enter the MAC address of the meter without colon in capital letters
(For example: if the MAC address of the meter is 00:80:f4:02:14:38, then
password is 0080F4021438).
• Guest (default password is Powerlogic@1)

WARNING
POTENTIAL COMPROMISE OF SYSTEM AVAILABILITY, INTEGRITY, AND
CONFIDENTIALITY
• Change default passwords at first use to help prevent unauthorized access
to device settings, controls, and information.
Failure to follow these instructions can result in death, serious injury, or
equipment damage.

In a continuous effort to encourage users on the awareness about the

cybersecurity best practices and the meters more cyber secure in their
applications, the users are forced to change the default factory-set password to a
complex password.

Changing user account password

NOTE: When you change your user account password, the user sessions get
terminated and you need to re-login to access the webpages.

NOTICE
LOSS OF ACCESS
Record your device's user and password information in a secure location.
Failure to follow these instructions can result in data loss and loss of
access to the device.

NOTICE
LOSS OF DATA OR PRODUCT CONFIGURATION
Do not let unauthorized personnel gain physical access to the device.
Failure to follow these instructions can result in data loss and loss of
access to the device.

1. Click the user account on the top right corner of the webpage.
2. Click Change Password button.
The Password Modification window opens.
3. Enter the Old Password, new Password and Confirm Password.
NOTE: The password must contain between 8 and 16 characters with at
least 1 number, 1 capital letter and 1 special character.
4. Click Apply Changes to save your new password.

Roles
Webpages access permissions are based on roles. You must be an administrator
to assign user access roles.

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User account Password Role Access

MAC address which is
unique for each meter
NOTE: Enter the MAC
address of the meter Full access to all webpages and its features with
without colon in capital read/write permission.
Administrator letters (For example: if Administrator
NOTE: Forced to change the default password
the MAC address of the
for system security the first time you log in.
meter is 00:80:
f4:02:14:38, then
password is
0080F4021438).

Read only access to Home, Monitoring,

Diagnostics and Maintenance tabs to view or
monitor the data.
NOTE:
Guest Powerlogic@1 Guest • Forced to change the default password
for system security the first time you log
in.
• No modify access to Firmware Upgrade
and Settings

Adding user accounts for webpages

In addition to the two default user accounts, you can create up to 4 user
accounts.
NOTE:
• If the Username or Password credentials of the Administrator user
account are lost, you can reset using another Administrator user
account.
• You can reset the webpage user account via meter HMI, if the Username
or Password credentials of the Administrator user account are lost
(Refer to Performing user account resets using the display, page 142).
1. Click Settings > User Management > User Accounts.
2. In the User Accounts section, click Add User.
The Add User section opens.
3. Enter the Username, Password details and assign the user a Role.
4. Click Apply Changes to save your changes to the meter.

Parameter Description

Username Enter a name (1 to 15 characters) for a new user.

NOTE: Username is case-sensitive and can contain special characters.

Password Enter a password (8 to 16 characters) for a new user.

NOTE: The password must contain between 8 and 16 characters with at least 1
number, 1 capital letter and 1 special character.

Confirm Password Confirm the password.

Role Assign a role for the user.

• Administrator
• Guest

Deleting user account

NOTE: You must have Administrator role access to delete the user accounts.
1. Click Settings > User Management > User Accounts.

2. In the User Accounts section, click icon.

The User Deletion dialog box opens.

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3. Click Yes to delete the user account.

Edit user account details

NOTE: You must have Administrator role access to change the user account
password and assign role to the user:
1. User account password reset:
a. Click Settings > User Management > User Accounts.

b. In the User Accounts section, click icon.

The Edit User section opens.
c. Enter the New Password and Confirm Password details.
NOTE: The password must contain between 8 and 16 characters
with at least 1 number, 1 capital letter and 1 special character.
d. Click Apply Changes to save your changes to the meter.
2. Assigning user role:
NOTE: To assign role to the user, you must also reset the password.
a. Click Settings > User Management > User Accounts.

b. In the User Accounts section, click icon.

The Edit User section opens.
c. From the drop-down list, assign the Role to the user.
d. Enter the New Password and Confirm Password details.
NOTE: The password must contain between 8 and 16 characters
with at least 1 number, 1 capital letter and 1 special character.
e. Click Apply Changes to save your changes to the meter.

Terminating user account sessions

NOTE: You must have Administrator role access to terminate the user
account sessions.
1. Click Settings > User Management > User Accounts.

2. In the User Accounts section, click icon.

The Terminate User Sessions dialog box opens with the warning message
“Are you sure you want to terminate sessions ? This will terminate all
active sessions for the user”.
3. Read the warning message and click Yes to terminate the user account
sessions.

Reading device registers using the webpages

You can use the webpages to read a specified block of Modbus registers from the
meter or from a slave device when the meter is acting as a gateway.
1. Navigate to Diagnostics > Communication > Read Device Registers.
2. Type the address of the device you want to read in the Device ID field.
3. Enter values in the Starting Register and Number of Registers fields.
4. Select the data format of the registers from the Data Type field that you want
to read in: Holding Registers, Input Registers, Output Coils, Input Coils.

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5. Select the number format from the Display Option field that you want to
display the value of the registers in: Decimal, Hexadecimal, Binary, ASCII
or Float.
6. Click Read.

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Communications
Ethernet communications
The meter supports Modbus TCP, BACnet/IP, EtherNet/IP, HTTP / HTTPS4, SNTP,
SNMP, SMTP, FTP / FTPS4, DNP3 protocols and can communicate at data
speeds up to 100 Mbps through its Ethernet communications port.
The meter supports a single IP address between two 10/100Base-T Ethernet
ports. The second Ethernet port functions as an Ethernet switch, which allows you
to have shorter Ethernet cable runs between the meters without requiring
additional Ethernet routers or repeaters. This helps simplify network connections
and reduce installation time and costs.
The meter supports a maximum of 128 concurrent TCP/IP connections, that are
shared between HTTP / HTTPS4, FTP / FTPS4, Modbus TCP and other TCP/IP
protocols.
The meter supports a maximum of three concurrent connections (sessions) using
the DNP3 protocol.

Ethernet configuration
In order to use Ethernet communications, you must configure your device’s IP
address; you must also configure the subnet and gateway information if required
by your network.
NOTE: For meters that do not have a display, you must configure each one
separately in order to set a unique IP address for each device.
You need to enter network information for any Ethernet servers used by the
device.
NOTE: Contact your network system administrator for your IP address and
other Ethernet network configuration values.
Configure your device’s Ethernet settings by using the display or directly
connecting to your meter and using a web browser to access the device’s
webpages. Modify your meter’s Ethernet settings to those provided by your
network system administrator before connecting the device to your local area
network (LAN).
After the meter’s Ethernet port is configured and connected to the LAN, you can
use ION Setup to configure other meter setup parameters.

Ethernet port setup

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
The meter is factory-configured with default Ethernet communications settings.
You must modify the default Ethernet settings before connecting the meter to your
local area network (LAN) using the meter webpages.
The default Ethernet communications settings are:
• IP method = Stored
• IP address = 169.254.0.10

4. Available only in latest firmware versions:

• PM5560 / PM5562 / PM5563 / PM5580 meter models: 4.0.0 and above
• PM5570 / PM5660 / PM5760 meter models: 6.0.0 and above
• PM5650 meter model: 4.10.0 and above
• PM5561 meter model: 12.0.0 and above
• PM5661 / PM5761 meter models: 14.0.0 and above

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• Subnet mask = 255.255.0.0

• Gateway = 0.0.0.0
• HTTP server = Enabled
• DPWS = Enabled
• EtherNet/IP = Enabled
• DNP3 = Disabled
• MAC = 00:80:67:8A:F6:64
• Device name = PM55-#xxxxxxxxxx, where xxxxxxxxxx is the meter’s factory
serial number (with leading zeros if serial number is less than 10 characters)
NOTE: Your meter’s serial communications port ID (Com1 ID) is used in both
Ethernet and serial communications; you need to change the Com1 ID meter
property in ION Setup if you modify the meter’s RS-485 address.

Performing initial Ethernet configuration using the webpages

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
The meter is factory-configured with default Ethernet settings, which you must
change before connecting the meter to your network.
For meters with a display, you can configure basic Ethernet settings using the
display. If you want to use Ethernet to communicate to meters without a display,
you need to perform the following steps to configure basic Ethernet settings before
you connect the meter to your network.
1. Disconnect your computer from the network. If your computer has wireless
communications, make sure you disable the wireless network connection as
well.
NOTE: After you disconnect your computer from the network, its IP
address should automatically update to a default IP address of 169.254.
###.### (where ### equals a number from 0 to 255) and a subnet mask
of 255.255.0.0. If your computer does not automatically update after
several minutes, contact your network administrator to set up a static IP
address.
2. Use an Ethernet cable to connect the computer to one of the meter’s Ethernet
ports.
3. Open web browser and enter the meter’s IP address in the address box.
4. Enter the Username and Password.
5. Based on your meter firmware version, click Settings > Ethernet Settings
OR click Settings > Communication > Ethernet Settings.

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6. Modify the Ethernet setup parameters with the settings your system
administrator assigned for the meter.

Parameter Description

MAC Address Displays the meter’s factory-programmed MAC address. This information is read-only
and cannot be changed.

IP Address Acquisition Mode This controls the network protocol for your device (which the meter uses to obtain its IP
address):
• DHCP: Dynamic Host Configuration Protocol
• BOOTp: Bootstrap Protocol
• Stored: The static value programmed in the IP Address setup register
• Default: Use 85.16 as the first two values of the IP address, then convert the last
two hexadecimal values of the MAC address to decimal and use this as the last two
values of the IP address
Example: MAC address = 00:80:67:82:B8:C8
Default IP address = 85.16.184.200
IP Address The Internet protocol address of your device.

Subnet Mask The Ethernet IP subnetwork address of your network.

Default Gateway The Ethernet IP gateway address of your network.

7. Click Save changes or Apply Changes to send and save the new settings to
the meter.
8. Click Logout to exit the meter’s webpages.
9. Re-establish the computer’s connection to your LAN (plug the computer’s
Ethernet cable back to your LAN connection or re-enable wireless
communications to the LAN).

Setting up Ethernet communications using the display

The Ethernet setup screen allows you to assign the meter a unique IP address so
you can use software to access the meter’s data or configure the meter remotely
through the Ethernet port.
Before configuring the Ethernet parameters, make sure you obtain your meter’s IP
address information from your network administrator or IT department.
1. Navigate to Maint > Setup.
2. Enter the setup passcode (default is “0”), then press OK.
3. Navigate to Comm > Enet.
4. Move the cursor to point to the parameter you want to modify, then press
Edit.
5. Modify the parameter as required, then press OK.
6. Move the cursor to point to the next parameter you want to modify, press Edit,
make your changes, then press OK.
7. Press the up arrow to exit.

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8. Press Yes to save your changes.

Parameter Values Description

IP Method Stored, Default, DHCP, This controls the network protocol for your device (what the meter uses to obtain
BOOTP its IP address).

Stored: Use the static value programmed in the IP Address setup register

Default: Use 85.16 as the first two values of the IP address, then convert the last
two hexadecimal values of the MAC address to decimal and use this as the last
two values of the IP address. Example: MAC address = 00:80:67:82:B8:C8
Default IP = 85.16.184.200

DHCP: Dynamic Host Configuration Protocol

BOOTP: Bootstrap Protocol

IP Address Contact your local network The Internet protocol address of your device.
administrator for parameter
values.
Subnet Contact your local network The Ethernet IP subnetwork address of your network (subnet mask).
administrator for parameter
values.
Gateway Contact your local network The Ethernet IP gateway address of your network.
administrator for parameter
values.
HTTP Server Enabled, Disabled Controls whether your device’s webserver and webpages are active or not.

FTP Enabled, Disabled Allows you to enable or disable FTP

(Auto-disables if idle for 20 minutes)**

DPWS Enabled, Disabled Allows you to enable or disable DPWS

EtherNet/IP Enabled, Disabled Allows you to enable or disable EtherNet/IP

DNP3* Enabled, Disabled Allows you to enable or disable DNP3

MAC 00:80:67:8A:F6:64 Displays the meter’s factory-programmed MAC address.This information is

read-only and cannot be changed.

Device Name (see description) This is the meter’s device name and is factory set to PM55-#xxx (where xxx is
the serial number of the meter). This can be used as a DNS entry that maps the
device name to the IP address assigned by the DHCP server.

*Available in specific meter models. Refer to Features differentiation matrix for PM5500 / PM5600 / PM5700 series, page 20 for the
availability.

**Refer to Restoration of temporarily disabled configuration settings in webpages, page 225 to know availability of these features on your
meter model.

NOTE:
An exclamation mark beside the IP address can indicate:
• that the IP address is being programmed. Wait a few seconds for the
IP address to appear to confirm that it is programmed.
• that there is a problem with the network. Check with your system
administrator for network issues.

Configuring basic Ethernet settings using the webpages

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
You can use the meter’s webpages to configure Ethernet settings.
1. Login to the meter webpages.
2. Based on your meter firmware version, click Settings > Ethernet Settings
OR click Settings > Communication > Ethernet Settings.
3. Modify the Ethernet setup parameters as required.

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4. Click Save changes or Apply Changes to send and save the new settings to
the meter.

Parameter Description

MAC Address Displays the meter’s factory-programmed MAC address. This information is read-only
and cannot be changed.

IP Address Acquisition Mode This controls the network protocol for your device (which the meter uses to obtain its IP
address):
• DHCP: Dynamic Host Configuration Protocol
NOTE: Fully qualified domain names are not supported. The device name is
not automatically sent to a DNS server when a DHCP request is sent. In order
to use device name instead of IP address, your IT administrator must manually
add the device name to the DNS.
• BOOTp: Bootstrap Protocol
• Stored: The static value you programmed in the IP Address setup register
• Default: Uses 85.16 as the first two values of the IP address, then converts the last
two hexadecimal values of the MAC address to decimal and uses this as the last
two values of the IP address. Example: MAC address = 00:80:67:82:B8:C8, default
IP = 85.16.184.200
IP Address The Internet protocol address of your device.

Subnet Mask The Ethernet IP subnetwork address of your network (subnet mask).

Default Gateway The Ethernet IP gateway address of your network.

Configuring advanced Ethernet parameters using the

webpages
NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
You can configure advanced Ethernet parameters, such as TCP keepalive,
connection timeouts and idle times, using the Advanced Ethernet Settings
webpage.
1. Login to the meter webpages.
2. Based on your meter firmware version, click Settings > Advanced Ethernet
Settings OR click Settings > Communication > Advanced Ethernet
Settings.
3. Modify the Ethernet setup parameters as required.

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4. Click Save changes or Apply Changes to send and save the new settings to
the meter.
NOTE: Click Default to reset the advanced Ethernet parameters to their
default values.
Refer to the table below for the following firmware versions:
• PM5560 / PM5562 / PM5563 / PM5580 meter models: 2.9.9 and earlier
• PM5570 / PM5660 / PM5760 meter models: 3.2.9 and earlier
• PM5650 meter model: 2.12.9 and earlier
• PM5561 meter model: 10.9.9 and earlier
• PM5661 / PM5761 meter models: 11.2.9 and earlier

Parameter Values Description

Time to Live 1-255 The maximum number of hops (in other words, devices such as
routers) that a TCP packet is allowed to pass through before it is
discarded
TCP Keep Alive 0-65000 How frequently (in seconds) the meter sends a TCP keepalive
packet.

A setting of 0 disables the sending of TCP keepalive packets.

BootP Timeout 0-60 The length of time (in seconds) that the meter waits for a response
from a BootP server (the default IP address is used after timeout if
no IP address is assigned.)

ARP Cache Timeout 0-65000 The length of time (in minutes) that ARP entries are kept in the ARP
cache
FTP Server Enabled, Disabled Enables or disables the meter’s internal FTP server

FTP Connection Idle Time 30-900 The length of time (in seconds) after which an idle FTP connection
is closed
HTTP Connection Idle Time 0-65000 The length of time (in seconds) after which an idle HTTP connection
is closed
HTTP Port Number 80, 1024- 65000 The TCP port used for HTTP messages. The following port
numbers are reserved for other network protocols and cannot be
used: 20 / 21 (FTP), 161 / 162 (SNMP) and 502 (Modbus TCP/IP).

HTTP Maximum Keepalives 0-65000 The number of times the meter sends a keepalive signal if it does
not receive a response

Modbus TCP/IP Server Connections 16, 32, 36, 40, 44, 48, 64 The number of TCP connections used for Modbus TCP
communications when the meter is functioning as an Ethernet
gateway

Modbus TCP/IP Server Connection Idle 0-32767 The length of time the meter waits for a Modbus TCP/IP device to
Time respond to a connection request initiated by the meter.

Refer to the table below for the following firmware versions:

• PM5560 / PM5562 / PM5563 / PM5580 meter models: 4.0.0 and above
• PM5570 / PM5660 / PM5760 meter models: 6.0.0 and above
• PM5650 meter model: 4.10.0 and above
• PM5561 meter model: 12.0.0 and above
• PM5661 / PM5761 meter models: 14.0.0 and above

Parameter Values Description

Time to Live 1-255 The maximum number of hops (in other words, devices such as
routers) that a TCP packet is allowed to pass through before it is
discarded.
TCP Keep Alive 0-65000 How frequently (in seconds) the meter sends a TCP keepalive
packet.

A setting of 0 disables the sending of TCP keepalive packets.

BootP Timeout 0-60 The length of time (in seconds) that the meter waits for a response
from a BootP server (the default IP address is used after timeout if
no IP address is assigned.).

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Parameter Values Description

ARP Cache Timeout 0-65000 The length of time (in minutes) that ARP entries are kept in the ARP
cache.
Enable HTTPS – By default the HTTPS is always enabled.

Hypertext Transfer Protocol Secure (HTTPS): HTTPS is a variant

of the standard web transfer protocol (HTTP) that adds a layer of
security on the data in transit through a Secure Socket Layer (SSL)
or Transport Layer Security (TLS) protocol connection. HTTPS
enables encrypted communication and secure connection between
a remote user and the meter.
HTTPS Port 443, 1024- 65000 The TCP port used for HTTPS messages. The following port
numbers are reserved for other network protocols and cannot be
used: 20 / 21 (FTP), 161 / 162 (SNMP) and 502 (Modbus TCP/IP).

Modbus TCP/IP Server Connections 16, 32, 36, 40, 44, 48, 64 The number of TCP connections used for Modbus TCP
communications when the meter is functioning as an Ethernet
gateway.

Modbus TCP/IP Server Connection Idle 0-32767 The length of time the meter waits for a Modbus TCP/IP device to
Time respond to a connection request initiated by the meter.

FTP Enabled, Disabled Enables or disables the meter’s internal FTP server.

Control Port 1-65534 Establishes connection between hosts.

Data Port 1-65534 Used for data transfer.

Connection Security Mode No Encryption, TLS/SSL Encryption for secure mode connection.
Implicit Encryption

Encrypted Control Port 1-65534 Establishes encrypted connection between hosts.

Encrypted Data Port 1-65534 Used for encrypted data transfer.

Using a serial communications converter to set up RS-485

You can use a communications converter (USB to RS-485 or RS-232 to RS-485)
to connect to the meter.
NOTE: Configuring the serial communications settings using this method may
cause ION Setup to lose communications when the changes are sent to your
meter. You must reconfigure ION Setup to match the new settings to re-
establish communications with your meter.
1. Configure the serial communications converter’s settings to be compatible
with the meter’s default communications settings.
2. Connect the meter’s RS-485 port to the serial communications converter.
3. Connect the communications converter to the computer.
4. Start ION Setup in Network mode.
5. Add a serial site and set its properties:
• Comm link = Serial
• Comm port = select which serial (or USB) port the communications
converter is attached to
• Baud rate = 19200
• Format = select a format with even parity
6. Add a meter to the site and set its properties:
• Type = PowerLogic™ PM5xxx power meter
• Unit ID = 1
7. Use the setup screens to modify the meter’s setup parameters.
8. Use the RS-485 Base Comm setup screen to modify the meter’s serial
communication settings.

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9. Click Send to save your changes to the meter. You need to reconfigure ION
Setup to match the changed settings in order to re-establish communications
with your meter.
NOTE: If you set the protocol to ASCII 7, ASCII 8 or Jbus, you cannot use
ION Setup to reconnect to the meter – ION Setup does not communicate
using these protocols.
10. Exit ION Setup.

RS-485 port settings

Parameter Values Description

Protocol Modbus RTU, Jbus, ASCII 8, ASCII 7 Select the communications format used to transmit data. The
protocol must be the same for all devices in a communications loop.

ION Setup does not support ASCII 8, ASCII 7 or Jbus protocols.

Address 1 to 247 Set the address for this device. The address must be unique for
each device in a communications loop. For Jbus protocol, set the
device ID to 255.

This value is used in both Modbus TCP/IP and serial

communications.
Baud rate 9600, 10200, 38400 Select the speed for data transmission. The baud rate must be the
same for all devices in a communications loop.

Parity Even, Odd, None Select None if the parity bit is not used. The parity setting must be
the same for all devices in a communications loop.

Serial communications
The meter supports serial communication through the RS-485 port.
In an RS-485 network, there is one master device, typically an Ethernet to RS-485
gateway. It provides the means for RS-485 communications with multiple slave
devices (for example, meters). For applications that require only one dedicated
computer to communicate with the slave devices, a USB to RS-485 converter can
be used to connect to the master device.
Up to 32 devices can be connected on a single RS-485 bus.

RS-485 network configuration

After you have wired the RS-485 port and powered up the meter, you must
configure the serial communications port in order to communicate with the meter.
Each device on the same RS-485 communications bus must have a unique
address and all connected devices must be set to the same protocol, baud rate,
and parity (data format).
NOTE: To communicate with the meter using ION Setup, you must set the
serial site and all connected devices in the RS-485 network to the same parity
setting.
For meters that do not have a display, you must first wire and configure each one
separately before connecting these meters to the same RS-485 bus.

RS-485 port setup

The meter is factory-configured with default serial communications settings that
you may need to modify before connecting the meter to the RS-485 bus.
The meter is factory-configured with the following default serial communications
settings:
• Protocol = Modbus RTU
• Address = 1

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• Baud rate = 19200

• Parity = Even
You can use a communications converter (USB to RS-485 or RS-232 to RS-485)
or Ethernet gateway device to connect to the meter.

Setting up serial communications using the display

The Serial setup screen allows you to configure the meter’s RS-485
communications port so you can use software to access the meter’s data or
configure the meter remotely.
1. Navigate to Maint > Setup.
2. Enter the setup passcode (default is “0”), then press OK.
3. Navigate to Comm > Serial.
4. Move the cursor to point to the parameter you want to modify, then press
Edit.
5. Modify the parameter as required, then press OK.
6. Move the cursor to point to the next parameter you want to modify, press Edit,
make your changes, then press OK.
7. Press the up arrow to exit. Press Yes to save your changes.

Parameter Values Description

Mode Slave, Gateway Set this to Gateway to enable the Ethernet gateway functionality. Set this to Slave
if you are adding the meter as a downstream device to an RS-485 network.

Protocol Modbus, Jbus, ASCII 8 Select the communications format used to transmit data. The protocol must be the
Bit, ASCII 7 Bit same for all devices in a communications loop.

Address 1 to 247 Set the address for this device. The address must be unique for each device in a
communications loop. For Jbus protocol, set the device ID to 255.

Baud Rate 9600, 19200, 38400 Select the speed for data transmission. The baud rate must be the same for all
devices in a communications loop.

Parity Even, Odd, None Select None if the parity bit is not used. The parity setting must be the same for all
devices in a communications loop.

Configuring serial settings using the webpages

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
The Serial Settings webpage allows you to configure the meter’s RS-485
communications.
1. Login to the meter webpages.
2. Based on your meter firmware version, click Settings > Serial Settings OR
click Settings > Communication > Serial Port Configuration.
3. Modify the serial settings as required.

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4. Click Save changes or Apply Changes.

NOTE: Click Defaults to reset the advanced serial port settings to their
default values.

Parameter Values Description

Mode Slave, Gateway Set this to Gateway to enable the Ethernet gateway functionality.
Set this to Slave if you are adding the meter as a downstream
device to an RS-485 network.
Protocol Modbus, Jbus, ASCII 8 Bit, Select the communications format used to transmit data. The
ASCII 7 Bit protocol must be the same for all devices in a communications loop.
NOTE: The protocol must be set to Modbus RTU or Jbus if you
are using the meter as an Ethernet gateway.

Address 1 to 247 Set the address for this device. The address must be unique for
each device in a communications loop.

Baud Rate 9600, 19200, 38400 Select the speed for data transmission. The baud rate must be the
same for all devices in a communications loop.

Parity Even, Odd, None Select None if the parity bit is not used. The parity setting must be
the same for all devices in a communications loop.

Modbus Broadcast Enabled, Disabled Set this to Enabled to if you want the gateway meter to forward
broadcast messages (sent to Unit ID 0) to the downstream serial
devices.
Response Timeout 5 0.1, 0.2, 0.3, 0.4, 0.5, 1, 2, 3, 4, Set the time the gateway meter waits for an answer from a
5, 6, 7, 8, 9, 10 downstream serial device before generating an exception response.

Delay Between Frames 5 0, 10, 20, 30, 40, 50, 60, 70, 80, The minimum time in milliseconds between the end of a received
90, 100 response and the beginning of a new request.

Set this parameter to help improve communications between the

gateway and downstream slave devices with slower response
times.
Silent Interval Extension 5 0 – 15 Set this parameter to extend the silent interval (used to mark the
end of a Modbus packet) beyond the default 3.5 characters defined
in the Modbus standard. After the defined character time elapses
without a new character, the gateway meter treats the next
character as the start of a new message.

Using an Ethernet gateway to set up RS-485

You can use an Ethernet gateway to connect to the meter and configure RS-485
settings.
NOTE: Configuring the serial communications settings using this method may
cause ION Setup to lose communications when the changes are sent to your
meter. You must reconfigure ION Setup to match the new settings to re-
establish communications with your meter.
1. Disconnect all serial devices presently connected to the Ethernet gateway’s
RS-485 port.
2. Configure the Ethernet gateway’s serial port settings to match the meter’s
default serial communications settings:
– Baud rate = 19200
– Parity = Even
3. Connect the meter’s RS-485 port to the Ethernet gateway.
4. Connect the Ethernet gateway to the LAN.
5. Start ION Setup in Network mode.

5. These are advanced settings that you can adjust if you have communications errors when communicating through the gateway to the
downstream serial devices. They only apply if the meter is functioning as a gateway, and you should only change these settings if you
have an advanced knowledge of Modbus communications and your communications network.

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6. Add an Ethernet gateway site and set its properties:

– IP address = IP address of the Ethernet gateway
– Port = 502 (for Modbus RTU)
7. Add a meter to the site and set its properties:
– Type = PowerLogic™ PM5xxx power meter
– Unit ID = 1
8. Use the RS-485 Base Comm setup screen to modify the meter’s serial
communications settings.
9. Click Send to save your changes to the meter.
NOTE: If you set the protocol to ASCII 7, ASCII 8 or Jbus, you cannot use
ION Setup to reconnect to the meter – ION Setup does not communicate
using these protocols.

Parameter Values Description

Protocol Modbus RTU, Jbus, ASCII 8, Select the communications format used to transmit data. The
ASCII 7 protocol must be the same for all devices in a communications loop.
NOTE: ION Setup does not support ASCII 8, ASCII 7 or Jbus
protocols.

Address 1 to 247 Set the address for this device. The address must be unique for
each device in a communications loop.

This value is used in both Modbus TCP/IP and serial

communications.
Baud Rate 9600, 19200, 38400 Select the speed for data transmission. The baud rate must be the
same for all devices in a communications loop.

Parity Even, Odd, None Select None if the parity bit is not used. The parity setting must be
the same for all devices in a communications loop.

Post-requisite: Reconfigure ION Setup to match the changed settings in order to

re-establish communications with your meter.

BACnet/IP
BACnet/IP protocol allows communication between the components of a building
automation and control system (for example, HVAC, lighting control, security
systems and related equipment).
The BACnet/IP protocol defines a number of services that are used to
communicate between devices and the objects that are acted upon by those
services.

Term Definition
APDU Application protocol data unit, that data portion of a BACnet
message.

Confirmed message A message for which the device expects an answer.

COV, COV increment Change of value, sets the amount by which a value has to change in
order for the meter to send a subscription notification.

Device A BACnet device is a unit that is designed to understand and use

BACnet protocol (for example, a BACnet-enabled meter or software
program). It contains information about the device and device data in
objects and object properties. Your meter is a BACnet device.

Object Represents the device and device data. Each object has a type (for
example, analog input or binary input) and has a number of
properties.

Present value The current value of an object.

Property The smallest piece of information in BACnet communications, it

consists of a name, data type and value.

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Term Definition

Service Messages from one BACnet device to another.

Subscription A relationship between a BACnet client and the meter, so that when
the present value property of an object changes on the meter, a
notification is sent to the client.
Subscription notification The message the meter sends to indicate a COV event has occurred.

Unconfirmed message A message for which the device does not expect an answer.

BACnet Broadcast A BACnet/IP device (or software application) residing on a BACnet/

Management Device IP subnet that forwards BACnet broadcast messages from devices
(BBMD) on its subnet to peer BBMDs and registered foreign devices on other
subnets.
Foreign device A BACnet/IP device (or software application) that resides on a
remote IP subnet and registers with a BBMD to facilitate the sending
and receiving of broadcast messages to/from devices accessible by
the BBMD.

Supported BACnet features

Your meter supports specific BACnet components and standard objects.
The meter’s BACnet/IP protocol support is certified by BACnet International. Go to
www.bacnetinternational.org or www.se.com and search for your meter model to
access the PICS (Protocol Implementation Conformance Statement) for your
meter.

Supported BACnet components

BACnet component Description

Protocol version 1
Protocol revision 14
Standardized device profile (Annex L) BACnet Application Specific Controller (B-ASC)

BACNet Interoperability Building Blocks (Annex K) • DS-RP-B (Data Sharing - Read Property - B)
• DS-RPM-B (Data Sharing - Read Property Multiple - B)
• DS-WP-B (Data Sharing - Write Property - B)
• DS-WPM-B (Data Sharing - Write Property Multiple - B)
• DS-COV-B (Data Sharing - COV - B)
• DM-DDB-B (Device Management - Dynamic Device Binding - B)
• DM-DOB-B (Device Management - Dynamic Object Binding - B)
• DM-DCC-B (Device Management - Device Communication Control - B)

BACnet/IP (Annex J) BACnet communication internet protocol

Data link layer options UDP

Character set ANSI X3.4/UTF-8

Supported services • subscribeCOV
• readProperty
• readPropertyMultiple
• writeProperty
• writePropertyMultiple
• deviceCommunicationControl
• who-HAS
• who-Is
• I-Am
• I-Have
• Confirmed COV notification
• Unconfirmed COV notification
Segmentation The meter does not support segmentation

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BACnet component Description

Static device address binding The meter does not support static device address binding

Networking options The meter supports registration as a foreign device

Supported standard object types

NOTE: The BACnet protocol allows you to set the out-of-service property of
an object to true and write a value to that property for testing purposes. In this
case, your BACnet software displays the value you wrote to the object, not the
actual value from the meter and the system it is monitoring. Make sure you set
the out-of-service property of all objects to false before you put the meter into
service.

Object type Optional properties Writeable properties Conditional writeable

supported supported properties supported

Device Object • Location • Object_Name —

• Description • Object_Identifier
• Local_Time • Location
• Local_Date • Description
• Active_COV_ • APDU_Timeout
Subscriptions
• Number_Of_APDU_
• Profile_Name Retries

Analog Input Object • Description • Out_Of_Service Present_Value

• Reliability • COV_Increment
• COV_Increment

Binary Input Object • Description Out_Of_Service Present_Value

• Reliability

Multi-state Input Object • Description Out_Of_Service Present_Value

• Reliability
• State_Text

BACnet/IP communications implementation

Your meter's BACnet implementation includes specific behaviors and
configuration.

Basic configuration for BACnet communications

Before communicating with the meter via BACnet protocol, make sure the basic
BACnet settings are configured appropriately for your network. The Device ID
must be unique in your BACnet IP network.

Change of Value (COV) subscriptions

The meter supports up to 20 COV subscriptions. You can add COV subscriptions
to Analog Input, Binary Input and Multi-state Input objects using your BACnet-
compatible software.

Configuring BACnet/IP settings using the display

Use the meter’s display to configure BACnet/IP settings if required.
1. Navigate to Maint > Setup.
2. Enter the setup passcode (default is “0”), then press OK.
3. Navigate to Comm > BACnet.

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4. Move the cursor to point to the parameter you want to modify, then press
Edit.
5. Modify the parameter as required, then press OK.
6. Move the cursor to point to the next parameter you want to modify, press Edit,
make your changes, then press OK.
7. Press the up arrow to exit.

Basic BACnet/IP settings available using the display

Parameter Values Description

BACnet Status Enabled, Disabled Enable or disable BACnet/IP communications with the meter

Device ID 1 – 4194302 Enter the ID of the meter on your BACnet network. The ID must be
unique on the network.

UDP Port 1024 – 65535 Enter the port the meter uses for BACnet/IP communications. The
default is the standard BACnet/IP port (47808).

Foreign device settings available using the display

Parameter Values Description

BBMD Status Enabled, Disabled Enable or disabled registration of the meter as a foreign device.

BBMD IP Contact your local network Enter the IP address of the BACnet/IP Broadcast Management
administrator for parameter Device (BBMD), if you use a BBMD on your network.
values.
BBMD Port 1024 – 65535 Enter the port number that is used for communications with the
BBMD. The default is the standard BACnet/IP port (47808)

BBMD TTL (sec) 0 – 65535 The length of time (in seconds) the BBMD keeps an entry for this
device in its foreign device table.

Configuring BACnet/IP settings using the webpages

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
Use the meter’s webpages to configure BACnet/IP settings if required.
1. Login to the meter webpages.
2. Based on your meter firmware version, click Settings > BACnet/IP Settings
OR click Settings > Communication > BACnet/IP Settings.
3. Configure the settings as required for your BACnet network.

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4. Click Save changes or Apply Changes.

Basic BACnet/IP settings available using the webpages

Parameter Values Description

BACnet/IP Enable Yes, No Enable or disable BACnet/IP communications with the meter

Device ID 1 – 4194302 Enter the ID of the meter on your BACnet network. The ID must be
unique on the network.

Port 1024 – 65535 Enter the port the meter uses for BACnet/IP communications. The
default is the standard BACnet/IP port (47808).

Foreign device settings available using the webpages

Parameter Values Description

BBMD Enable Yes, No Enable or disabled registration of the meter as a foreign device.

BBMD IP Contact your local network Enter the IP address of the BACnet/IP Broadcast Management
administrator for parameter Device (BBMD), if you use a BBMD on your network.
values.
BBMD Port 1024 – 65535 Enter the port number that is used for communications with the
BBMD. The default is the standard BACnet/IP port (47808).

BBMD TTL (Time To Live) 0 – 65535 The length of time (in seconds) the BBMD keeps an entry for this
device in its foreign device table.

BACnet objects

Device object
Your meter has a Device object which describes the meter to the BACnet network.
The following table outlines the properties of the Device object, whether a property
is read-only or read-write, and if the value of the property is stored in the meter’s
nonvolatile onboard memory.

Device object property R/W Stored Possible values Description

Object_Identifier R/W Y See description The unique device ID number for the meter, in
the format of <device, #>.

The meter ships from the factory with a device

ID equal to the last 6 digits of the serial
number.
Object_Name R/W Y See description A configurable name for the meter.

The meter ships from the factory with a name

of <model name>_<serial number> (for
example, PM5560_0000000000).

Object_Type R — Device The object type for the meter.

System_Status R — Operational This value of this property is always

Operational.

Vendor_Name R — Schneider Electric Meter manufacturer

Vendor_Identifier R — 10 The BACnet vendor identifier for Schneider

Electric.
Model_Name R — varies Device model (for example, PM5560) and
serial number in the format <model name>_
<serial number> (for example, PM5560_
0000000000).

Firmware_Revision R — varies BACnet firmware version, stored in an x.x.x

format (for example, 1.9.0).

Application_Software_Version R — varies Meter firmware version, stored in an x.x.x

format (for example, 1.0.305).

Description R/W Y configurable Optional description of the meter, limited to 64

characters.

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Device object property R/W Stored Possible values Description

Location R/W Y configurable Optional description of the meter’s location,

limited to 64 characters.
Protocol_Version R — varies BACnet protocol version (for example, version
1)

Protocol_Revision R — varies BACnet protocol revision (for example,

revision 14)

Protocol_Services_Supported R — 0000 0100 0000 1011 The BACnet services supported by the meter:
1100 1000 0000 0000 subscribeCOV, readProperty,
0110 0000 0 readPropertyMultiple, writeProperty,
writePropertyMultiple,
deviceCommunicationControl,
ReinitializeDevice, who-HAS, who-Is

Protocol_Object_Types_ R — 1001 0000 1000 0100 The BACnet object types supported by the
Supported 0000 0000 0000 0000 meter: analog input, binary input, multi-state
0000 0000 0000 0000 input, device.
0000 000
Object_list R — See description List of objects in the meter.

Max_APDU_Length_Accepted R — 1476 The maximum packet size (or application

protocol data unit) that the meter can accept,
in bytes.

Segmentation_Supported R — 0x03 The meter does not support segmentation.

Local_Date R — varies Current date on the meter

NOTE: Use the display, the webpages or
ION Setup to set the meter’s date.

Local_Time R — varies Current time on the meter

NOTE: Use the display, the webpages or
ION Setup to set the meter’s time. You
can also set up SNTP time
synchronization using the webpages.

APDU_Timeout R/W Y 1000 – 30000 The amount of time (in milliseconds) before
the meter tries to resend a confirmed message
that has not been answered.
Number_Of_APDU_Retries R/W Y 1 – 10 The number of times the meter tries to resend
an unanswered confirmed request.

Device_Address_Binding R — — Device address binding table is always blank

because the meter does not initiate the who-Is
service.
Database_Revision R Y varies A number that increments when the object
database on the meter changes (for example,
when an object is created or deleted or the ID
of an object changes).

Active_COV_Subscriptions R — varies List of COV subscriptions currently active on

the meter.
Profile_Name R — varies Device identifier that records the meter
manufacturer, the meter family and the
specific meter model (for example, 10-
PM5000-PM5560).

Analog Input objects

Your meter has a number of Analog Input objects that provide meter values and
information on meter settings.
The following tables list the Analog Input objects along with the units and default
COV value for each object (if applicable).

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Real-time measurements
Object ID Object name Units Default COV Description

3000 Current - Ph A A 50 Current phase A

3002 Current - Ph B A 50 Current phase B

3004 Current - Ph C A 50 Current phase C

3006 Current - Neutral A 50 Neutral current

3008 Current - Ground A 50 Ground current
3010 Current - Avg A 50 Current average

3012 Current Unb - Ph A % 20 Current unbalance phase A

3014 Current Unb - Ph B % 20 Current unbalance phase B

3016 Current Unb - Ph C % 20 Current unbalance phase C

3018 Current Unb - Worst % 20 Current unbalance worst

3020 Voltage - A-B V 10 Voltage A-B

3022 Voltage - B-C V 10 Voltage B-C

3024 Voltage - C-A V 10 Voltage C-A

3026 Voltage - Avg L-L V 10 Voltage L-L Avg

3028 Voltage - A-N V 10 Voltage A-N

3030 Voltage - B-N V 10 Voltage B-N

3032 Voltage - C-N V 10 Voltage C-N

3036 Voltage - Avg L-N V 10 Voltage L-N Avg

3038 Voltage Unb - A-B % 20 Voltage unbalance A-B

3040 Voltage Unb - B-C % 20 Voltage unbalance B-C

3042 Voltage Unb - C-A % 20 Voltage unbalance C-A

3044 Voltage Unb - Worst L-L % 20 Voltage unbalance L-L worst

3046 Voltage Unb - A-N % 20 Voltage unbalance A-N

3048 Voltage Unb - B-N % 20 Voltage unbalance B-N

3050 Voltage Unb - C-N % 20 Voltage unbalance C-N

3052 Voltage Unb - Worst L-N % 20 Voltage unbalance L-N worst

3110 Frequency Hz 10 Frequency

3100* Residual current - I5 mA 0.001 I5 residual current

3102* Residual current - I6 mA 0.001 I6 residual current
44042* Analog Input 1 - Raw Value A 0.001 Raw value of analog input 1

44044* Analog Input 1 - Scaled Value — 1 Scaled value of analog input 1

44096* Analog Input 2 - Raw Value A 0.001 Raw value of analog input 2

44098* Analog Input 2 - Scaled Value — 1 Scaled value of analog input 2

*Available in specific meter models. Refer to Features differentiation matrix for PM5500 / PM5600 / PM5700 series, page 20 for the
availability.

Power and power factor

Object ID Object name Units Default COV Description

3054 Active Power - Ph A kW 10 Active power phase A

3056 Active Power - Ph B kW 10 Active power phase B

3058 Active Power - Ph C kW 10 Active power phase C

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Object ID Object name Units Default COV Description

3060 Active Power - Total kW 10 Active power total

3062 Reactive Power - Ph A kVAR 10 Reactive power phase A

3064 Reactive Power - Ph B kVAR 10 Reactive power phase B

3066 Reactive Power - Ph C kVAR 10 Reactive power phase C

3068 Reactive Power - Total kVAR 10 Reactive power total

3070 Apparent Power - Ph A kVA 10 Apparent power phase A

3072 Apparent Power - Ph B kVA 10 Apparent power phase B

3074 Apparent Power - Ph C kVA 10 Apparent power phase C

3076 Apparent Power - Total kVA 10 Apparent power total

3078 Power Factor - Ph A — 0.2 Power factor phase A

3080 Power Factor - Ph B — 0.2 Power factor phase B

3082 Power Factor - Ph C — 0.2 Power factor phase C

3084 Power Factor - Total — 0.2 Power Factor Total

Energy and energy by tariff measurements

Object ID Object name Units Default COV Description

2700 Active Energy Delvd kWh 100 Active energy delivered

2702 Active Energy Rcvd kWh 100 Active energy received

2704 Active Energy Delvd + Rcvd kWh 100 Active energy delivered + received

2706 Active Energy Delvd - Rcvd kWh 100 Active energy delivered – received

2708 Reactive Energy Delvd kVARh 100 Reactive energy delivered

2710 Reactive Energy Rcvd kVARh 100 Reactive energy received

2712 Reactive Energy Delvd + Rcvd kVARh 100 Reactive energy delivered +
received
2714 Reactive Energy Delvd - Rcvd kVARh 100 Reactive energy delivered –
received
2716 Apparent Energy Delvd kVAh 100 Apparent energy delivered

2718 Apparent Energy Rcvd kVAh 100 Apparent energy received

2720 Apparent Energy Delvd + Rcvd kVAh 100 Apparent energy delivered +
received
2722 Apparent Energy Delvd - Rcvd kVAh 100 Apparent energy delivered –
received
4191 Applicable Tariff Energy Rate — 1 Denotes the active tariff:

0 = Multi Tariff feature is disabled

1 = tariff 1 active

2 = tariff 2 active

3 = tariff 3 active

4 = tariff 4 active

5 = tariff 5 active

6 = tariff 6 active

7 = tariff 7 active

8 = tariff 8 active
4800 Active Energy Delvd (Tariff 1) kWh 100 Tariff 1 active energy import

4802 Active Energy Delvd (Tariff 2) kWh 100 Tariff 2 active energy import

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Object ID Object name Units Default COV Description

4804 Active Energy Delvd (Tariff 3) kWh 100 Tariff 3 active energy import

4806 Active Energy Delvd (Tariff 4) kWh 100 Tariff 4 active energy import

4808 Active Energy Delvd (Tariff 5) kWh 100 Tariff 5 active energy import

4810 Active Energy Delvd (Tariff 6) kWh 100 Tariff 6 active energy import

4812 Active Energy Delvd (Tariff 7) kWh 100 Tariff 7 active energy import

4814 Active Energy Delvd (Tariff 8) kWh 100 Tariff 8 active energy import

Power demand
Object ID Object name Units Default COV Description

3764 Dmd - Active Power Last kW 10 Demand - Active power last

3766 Dmd - Active Power Present kW 10 Demand - Active power present

3768 Dmd - Active Power Pred kW 10 Demand - Active power predicted

3770 Dmd - Active Power Peak kW 10 Demand - Active power peak

3780 Dmd - Reactive Power Last kVAR 10 Demand - Reactive power last

3782 Dmd - Reactive Power Present kVAR 10 Demand - Reactive power present

3784 Dmd - Reactive Power Pred kVAR 10 Demand - Reactive power predicted

3786 Dmd - Reactive Power Peak kVAR 10 Demand - Reactive power peak

3796 Dmd - Apparent Power Last kVA 10 Demand - Apparent power last

3798 Dmd - Apparent Power Present kVA 10 Demand - Apparent power present

3800 Dmd - Apparent Power Pred kVA 10 Demand - Apparent power

predicted

3802 Dmd - Apparent Power Peak kVA 10 Demand - Apparent power peak

3972 Dmd - Active Power Ph A Last kW 10 Demand - Active power phase A

last
3974 Dmd - Active Power Ph A Present kW 10 Demand - Active power phase A
present

3976 Dmd - Active Power Ph A Pred kW 10 Demand - Active power phase A

predicted

3978 Dmd - Active Power Ph A Peak kW 10 Demand - Active power phase A

peak

3988 Dmd - Reactive Power Ph A Last kVAR 10 Demand - Reactive power phase A
last
3990 Dmd - Reactive Power Ph A kVAR 10 Demand - Reactive power phase A
Present present

3992 Dmd - Reactive Power Ph A Pred kVAR 10 Demand - Reactive power phase A
predicted

3994 Dmd - Reactive Power Ph A Peak kVAR 10 Demand - Reactive power phase A
peak

4004 Dmd - Apparent Power Ph A Last kVA 10 Demand - Apparent power phase A
last
4006 Dmd - Apparent Power Ph A kVA 10 Demand - Apparent power phase A
Present present

4008 Dmd - Apparent Power Ph A Pred kVA 10 Demand - Apparent power phase A
predicted

4010 Dmd - Apparent Power Ph A Peak kVA 10 Demand - Apparent power phase A
peak

4020 Dmd - Active Power Ph B Last kW 10 Demand - Active power phase B

last

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Object ID Object name Units Default COV Description

4022 Dmd - Active Power Ph B Present kW 10 Demand - Active power phase B

present

4024 Dmd - Active Power Ph B Pred kW 10 Demand - Active power phase B

predicted

4026 Dmd - Active Power Ph B Peak kW 10 Demand - Active power phase B

peak

4036 Dmd - Reactive Power Ph B Last kVAR 10 Demand - Reactive power phase B
last
4038 Dmd - Reactive Power Ph B kVAR 10 Demand - Reactive power phase B
Present present

4040 Dmd - Reactive Power Ph B Pred kVAR 10 Demand - Reactive power phase B
predicted

4042 Dmd - Reactive Power Ph B Peak kVAR 10 Demand - Reactive power phase B
peak

4052 Dmd - Apparent Power Ph B Last kVA 10 Demand - Apparent power phase B
last
4054 Dmd - Apparent Power Ph B kVA 10 Demand - Apparent power phase B
present

4056 Dmd - Apparent Power Ph B Pred kVA 10 Demand - Apparent power phase B
predicted

4058 Dmd - Apparent Power Ph B Peak kVA 10 Demand - Apparent power phase B
peak

4068 Dmd - Active Power Ph C Last kW 10 Demand - Active power phase C

last
4070 Dmd - Active Power Ph C Present kW 10 Demand - Active power phase C
present

4072 Dmd - Active Power Ph C Pred kW 10 Demand - Active power phase C

predicted

4074 Dmd - Active Power Ph C Peak kW 10 Demand - Active power phase C

peak

4084 Dmd - Reactive Power Ph C Last kVAR 10 Demand - Reactive power phase C
last
4086 Dmd - Reactive Power Ph C kVAR 10 Demand - Reactive power phase C
Present present

4088 Dmd - Reactive Power Ph C Pred kVAR 10 Demand - Reactive power phase C
predicted

4090 Dmd - Reactive Power Ph C Peak kVAR 10 Demand - Reactive power phase C
peak

4100 Dmd - Apparent Power Ph C Last kVA 10 Demand - Apparent power phase C
last
4102 Dmd - Apparent Power Ph C kVA 10 Demand - Apparent power phase C
Present present

4104 Dmd - Apparent Power Ph C Pred kVA 10 Demand - Apparent power phase C
predicted

4106 Dmd - Apparent Power Ph C Peak kVA 10 Demand - Apparent power phase C
peak

Current demand
Object ID Object name Units Default COV Description

3812 Dmd - Active Current Ph A Last A 10 Demand - Active current phase A

last
3814 Dmd - Current Ph A Present A 10 Demand - Current phase A present

3816 Dmd - Active Current Ph A Pred A 10 Demand - Active current phase A

predicted

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Object ID Object name Units Default COV Description

3818 Dmd - Active Current Ph A Peak A 10 Demand - Active current phase A

peak

3828 Dmd - Active Current Ph B Last A 10 Demand - Active current phase B

last
3830 Dmd - Current Ph B Present A 10 Demand - Current phase B present

3832 Dmd - Active Current Ph B Pred A 10 Demand - Active current phase B

predicted

3834 Dmd - Active Current Ph B Peak A 10 Demand - Active current phase B

peak

3844 Dmd - Active Current Ph C Last A 10 Demand - Active current phase C

last
3846 Dmd - Current Ph C Present A 10 Demand - Current phase C present

3848 Dmd - Active Current Ph C Pred A 10 Demand - Active current phase C

predicted

3850 Dmd - Active Current Ph C Peak A 10 Demand - Active current phase C

peak

3860 Dmd - Current Neutral Last A 10 Demand - Current neutral last

3862 Dmd - Current Neutral Present A 10 Demand - Current neutral present

3864 Dmd - Current Neutral Pred A 10 Demand - Current neutral predicted

3866 Dmd - Current Neutral Peak A 10 Demand - Current neutral peak

3876 Dmd - Average Current Last A 10 Demand - Average current last

3878 Dmd - Avg Current Present A 10 Demand - Average current present

3880 Dmd - Average Current Pred A 10 Demand - Average current

predicted

3882 Dmd - Average Current Peak A 10 Demand - Average current peak

Power quality

Object ID Object name Units Default COV Description

21300 THD Current - Ph A % 20 THD Current A

21302 THD Current - Ph B % 20 THD Current B

21304 THD Current - Ph C % 20 THD Current C

21306 THD Current - Ph N % 20 THD Current N

21308 THD Current - Ph G % 20 THD Current G

21310 thd Current - Ph A % 20 thd Current A

21312 thd Current - Ph B % 20 thd Current B

21314 thd Current - Ph C % 20 thd Current C

21316 thd Current - Ph N % 20 thd Current N

21318 thd Current - Ph G % 20 thd Current G

21320 Total Dmd Distortion % 20 Total Demand Distortion

21322 THD Voltage - A-B % 20 THD Voltage A-B

21324 THD Voltage - B-C % 20 THD Voltage B-C

21326 THD Voltage - C-A % 20 THD Voltage C-A

21328 THD Voltage - Avg L-L % 20 THD Voltage L-L

21330 THD Voltage - A-N % 20 THD Voltage A-N

21332 THD Voltage - B–N % 20 THD Voltage B-N

21334 THD Voltage - C-N % 20 THD Voltage C-N

21338 THD Voltage - Avg L-N % 20 THD Voltage L-N

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Object ID Object name Units Default COV Description

21340 thd Voltage - A-B % 20 thd Voltage A-B

21342 thd Voltage - B-C % 20 thd Voltage B-C

21344 thd Voltage - C-A % 20 thd Voltage C-A

21346 thd Voltage - Avg L-L % 20 thd Voltage L-L

21348 thd Voltage - A-N % 20 thd Voltage A-N

21350 thd Voltage - B-N % 20 thd Voltage B-N

21352 thd Voltage - C-N % 20 thd Voltage C-N

21356 thd Voltage - Avg L-N % 20 thd Voltage L-N

Meter information
The following table lists Analog Input objects that provide information about the
meter and its configuration.
NOTE: You can access the meter’s configuration information over BACnet
communications. However, you must use the display, meter webpages or ION
Setup to configure the meter’s settings.

Object ID Object name Units Default COV Description

2000 Time since last meter power up Seconds 604800 Time since the meter was last
powered up

2004 Meter operation timer Seconds 604800 Total meter operation time

2014 Number of phases — 1 Number of phases

1, 3

2015 Number of wires — 1 Number of wires

2, 3, 4

2017 Nominal frequency Hz 1 Nominal frequency

50, 60

2025 Number of VTs — 1 Number of VTs

0, 2, 3

2026 VT primary V 1 VT Primary

2028 VT secondary V 1 VT Secondary

2029 Number of CTs — 1 Number of CTs

1, 2, 3, 4

2030 CT primary A 1 CT Primary

2031 CT secondary A 1 CT Secondary

2060* RCM – I5 toroid turns — 1000 RCM toroid turns of I5

2062* RCM – I6 toroid turns — 1000 RCM toroid turns of I6
*Available in specific meter models. Refer to Features differentiation matrix for PM5500 / PM5600 / PM5700 series, page 20 for the
availability.

Binary Input objects

Your meter has a number of Binary Input objects that provide the status
information from the meter’s I/O.
The following table lists the Binary Input (BI) objects available on the meter.

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Object ID Object name Description

38416 – 38419 Digital Input 1 Status of digital inputs:

Digital Input 2 0 = on
1 = off
Digital Input 3*
NOTE: This information only applies if the digital input is
Digital Input 4* configured as a status input.

38448, 38449 Digital Output 1 Status of digital outputs:

Digital Output 2 0 = on
1 = off
*Available in specific meter models. Refer to Features differentiation matrix for PM5500 / PM5600 / PM5700 series, page 20 for the
availability.

Multi-state Input objects

Your meter has a number of Multi-state Input objects that provide information
about the meter’s I/O and power system settings.

Meter configuration multi-state input objects

Object ID Object name Object name / description

2016 Power System Type Power system configuration:

0 = 1PH2W L-N
1 = 1PH2W L-L
2 = 1PH3W L-L with N
3 = 3PH3W ungrounded delta
4 = 3PH3W corner grounded delta
5 = 3PH3W ungrounded wye
6 = 3PH3W grounded wye
7 = 3PH3W resistance grounded wye
8 = 3PH4W center-tapped open delta
9 = 3PH4W center-tapped delta
10 = 3PH4W ungrounded wye
11 = 3PH4W grounded wye
12 = 3PH4W resistance grounded wye

2036 VT Connection Type VT connection type:

0 = Direct connect
1 = Delta (2 VT)
2 = Wye (3 VT)
3 = L-N (1 VT)
4 = L-L (1 VT)
5 = L-L with N (2 VT)

3701 Demand Method - Power Power demand method:

0 = Thermal demand
1 = Timed interval sliding block
2 = Timed interval block
3 = Timed interval rolling block
4 = Input synchronized block
5 = Input synchronized rolling block
6 = Command synchronized block
7 = Command synchronized rolling block
8 = Clock synchronized block
9 = Clock synchronized rolling block

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Object ID Object name Object name / description

3711 Demand Method - Current Current demand method:

0 = Thermal demand
1 = Timed interval sliding block
2 = Timed interval block
3 = Timed interval rolling block
4 = Input synchronized block
5 = Input synchronized rolling block
6 = Command synchronized block
7 = Command synchronized rolling block
8 = Clock synchronized block
9 = Clock synchronized rolling block

3721 Demand Method - Input Metering Input metering demand method:

0 = Thermal demand
1 = Timed interval sliding block
2 = Timed interval block
3 = Timed interval rolling block
4 = Input synchronized block
5 = Input synchronized rolling block
6 = Command synchronized block
7 = Command synchronized rolling block
8 = Clock synchronized block
9 = Clock synchronized rolling block

I/O multi-state input objects

The following table lists the Multi-state Input objects that provide information about
meter’s I/O configuration.

Object ID Object name Description

7274, 7298, 7322, 7346 Digital Input 1 Mode Digital input control mode
0 = Normal (Alarm)
Digital Input 2 Mode
1 = Demand Interval Sync Pulse
Digital Input 3 Mode*
2 = Multi-tariff Control
Digital Input 4 Mode* 3 = Input Metering

9673, 9681 Digital Output Mode 1 Digital output control mode

0 = External
Digital Output Mode 2
1 = Demand Sync
2 = Alarm
3 = Energy

*Available in specific meter models. Refer to Features differentiation matrix for PM5500 / PM5600 / PM5700 series, page 20 for the
availability.

EtherNet/IP
EtherNet/IP is the name given to the Common Industrial Protocol (CIP), as
implemented over standard Ethernet (IEEE 802.3 and the TCP/IP protocol suite).

EtherNet/IP features overview

The EtherNet/IP and related features are available in firmware version 10.6.3 and
above for PM5561 / PM5661 / PM5761 meter models and firmware version 2.5.4
and above for all the other meter models.
The CIP application layer defines a set of application objects and device profiles
that define common interfaces and behaviors. In addition, CIP communication

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services enable end-to-end communication between devices on the different CIP

networks.
EtherNet/IP maps the CIP communication services to Ethernet and TCP/IP,
enabling multi-vendor interoperability between devices on Ethernet as well as with
the other CIP networks.
EtherNet/IP defines two primary types of communications:
• Cyclical Exchanges (Implicit Exchanges)
• Messaging (Explicit Exchanges)

Cyclical Exchanges (Implicit Exchanges)

The tables below gives description of the assembly sets supported by meters.
The size of assembly instances are as follows:
• Assembly input 100: 240 bytes
• Assembly output 150: 4 bytes
• Assembly configuration: 0

Assembly input 100

Word Number Parameter

0 Current A
2 Current B
4 Current C
6 Current N
8 Current G
10 Current Avg

12 Current Unbalance A
14 Current Unbalance B
16 Current Unbalance C
18 Current Unbalance Worst
20 Voltage A-B

22 Voltage B-C

24 Voltage C-A

26 Voltage L-L Avg

28 Voltage A-N

30 Voltage B-N

32 Voltage C-N

34 –

36 Voltage L-N Avg

38 Voltage Unbalance A-B

40 Voltage Unbalance B-C

42 Voltage Unbalance C-A

44 Voltage Unbalance L-L Worst

46 Voltage Unbalance A-N

48 Voltage Unbalance B-N

50 Voltage Unbalance C-N

52 Voltage Unbalance L-N Worst

54 Active Power A

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Assembly input 100 (Continued)

Word Number Parameter

56 Active Power B
58 Active Power C
60 Active Power Total
62 Reactive Power A
64 Reactive Power B
66 Reactive Power C
68 Reactive Power Total
70 Apparent Power A

72 Apparent Power B

74 Apparent Power C

76 Apparent Power Total

78 Power Factor A
80 Power Factor B
82 Power Factor C
84 Power Factor Total
86 Displacement Power Factor A

88 Displacement Power Factor B

90 Displacement Power Factor C

92 Displacement Power Factor Total

94 Frequency

96 Active Energy Delivered (Into Load)

98 Active Energy Received (Out of Load)

100 Active Energy Delivered + Received

102 Active Energy Delivered- Received

104 Reactive Energy Delivered

106 Reactive Energy Received

108 Reactive Energy Delivered + Received

110 Reactive Energy Delivered - Received

112 Apparent Energy Delivered

114 Apparent Energy Received

116 Apparent Energy Delivered + Received

118 Apparent Energy Delivered - Received

Assembly output 150

Word Number Parameter

0 Dummy parameter

1 Dummy parameter

Messaging (Explicit Exchanges)

The following objects can be accessed through explicit exchanges by meters.

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Object classes
The object classes are detailed in the following table:

Object class Class ID No. of Description

instances
Identity 01 hex 1 Supports the reset service

Message router 02 hex 1 Explicit message connection

Assembly 04 hex 2 Defines I/O data format

Connection manager 06 hex 1 Manages the internal resources associated with both I/O and explicit messaging
conditions
TCP/IP interface F5 hex 1 TCP/IP configuration

Ethernet link F6 hex 1 Counter and status information

Port object F4 hex 1 Describes the communication interfaces that are present on the device and
visible to CIP
Base energy 4E hex 1 Acts as an energy supervisor for CIP energy implementations

Electrical energy 4F hex 1 Provides unified electrical energy reporting capability for CIP enabled devices
and processes

Identity object (01 hex)

The identity object provides identification and status information about the meter.

Class code

Hexadecimal Decimal
01 hex 1

Class attributes

Attribute Access Name Data type Description Semantics of values

ID
1 Get Revision UINT Revision of this object The current value assigned
to this attribute is one (01).
If updates that require an
increase in this value are
made, then the value of this
attribute increases by 1

2 Get Max instances UINT Maximum instance number of an The largest instance
object currently created in this number of a created object
class level of the device at this class hierarchy level

3 Get Number of instances UINT Number of object instances The number of object
currently created at this class instances at this class
level of the device hierarchy level

6 Get Max ID number of class UINT The attribute ID number of the -

attribute last class attribute of the class
definition implemented in the
device
7 Get Max ID number of instance UINT The attribute ID number of the -
attribute last instance attribute of the
class definition implemented in
the device

Instance attributes

Attribute Access Name Data type Description Semantics of values

ID
1 Get Vendor ID UINT Identification of each vendor by -
number
2 Get Device type UINT Indication of general type of -
product

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Instance attributes (Continued)

Attribute Access Name Data type Description Semantics of values

ID
3 Get Product code UINT Identification of a particular -
product of an individual vendor

4 Get Revision STRUCT of: Revision of the item the identity Identifies the revision of the
object represents item the identity object is
Major revision USINT representing
Minor revision USINT
5 Get Status WORD Summary status of device This attribute represents
the current status of the
entire device. Its value
changes as the state of the
device changes

6 Get Serial number UDINT Serial number of device This attribute is a number
used in conjunction with
the Vendor ID to form a
unique identifier for each
device on any CIP network

7 Get Product name SHORT_STRING Human readable identification This text string shall
represent a short
description of the product
represented by the Product
Code in attribute 3.

Supported class and instance services

Class service Instance service Service name Description

code code
01 hex 01 hex Get_Attribute_All Return all attributes

0E hex 0E hex Get_Attribute_Single Return single attribute

– 05 hex Reset Reset the communication module of the device

Message router object (02 hex)

Class code

Hexadecimal Decimal
02 hex 2

Class attributes

Attribute Access Name Data type Description Semantics of values

ID
1 Get Revision UINT Revision of this object The current value assigned
to this attribute is one (01).
If updates that require an
increase in this value are
made, then the value of this
attribute increases by 1

2 Get Max instances UINT Maximum instance number of an The largest instance
object currently created in this number of a created object
class level of the device at this class hierarchy level

3 Get Number of instances UINT Number of object instances The number of object
currently created at this class instances at this class
level of the device hierarchy level

4 Get Optional attribute list STRUCT of: List of optional instance A list of attribute numbers
attributes utilized in an object specifying the optional
class implementation attributes implemented in
the device for this class
Number of attributes UINT Number of attributes in the The number of attribute
optional attribute list numbers in the list

Optional attributes ARRAY of UINT List of optional attribute numbers The optional attribute
numbers

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Class attributes (Continued)

Attribute Access Name Data type Description Semantics of values

ID
6 Get Max ID number of class UINT The attribute ID number of the -
attribute last class attribute of the class
definition implemented in the
device
7 Get Max ID number of UINT The attribute ID number of the -
instance attribute last instance attribute of the class
definition implemented in the
device

Instance attributes

Attribute Access Name Data type Description Semantics of values

ID
1 Get Object_list STRUCT of: A list of supported objects Structure with an array of
object class codes
supported by the device

Number UINT Number of supported classes in the The number of class codes
classes array in the classes array

Classes ARRAY of UINT List of supported class codes The class codes supported
by the device

2 Get Number available UINT Maximum number of connections Count of the max number of
supported connections supported

Supported class and instance services

Service code Service name Description

01 hex Get_Attribute_All Return all attributes

0E hex Get_Attribute_Single Return single attribute

Assembly object (04 hex)

Class code

Hexadecimal Decimal
04 hex 4

Class attributes

Attribute ID Access Name Data type Description Semantics of values

1 Get Revision UINT Revision of this object The current value

assigned to this
attribute is two (02)

Instance attributes

Attribute ID Access Name Data type Description Semantics of values

3 Set Data ARRAY of - -

BYTE

Supported class and instance services

Service code Service name Description

0E hex Get_Attribute_Single Return single attribute

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Connection manager object (06 hex)

Class attributes

Attribute Access Name Data type Description Semantics of values

ID
1 Get Revision UINT Revision of this object The current value assigned
to this attribute is one (01).
If updates that require an
increase in this value are
made, then the value of
this attribute increases by 1

2 Get Max instances UINT Maximum instance number of The largest instance
an object currently created in number of a created object
this class level of the device at this class hierarchy level

3 Get Number of instances UINT Number of object instances The number of object
currently created at this class instances at this class
level of the device hierarchy level

4 Get Optional attribute list STRUCT of: List of optional instance A list of attribute numbers
attributes utilized in an object specifying the optional
class implementation attributes implemented in
the device for this class
Number of attributes UINT Number of attributes in the The number of attribute
optional attribute list numbers in the list

Optional attributes ARRAY of List of optional attribute The optional attribute

UINT numbers numbers
6 Get Max ID number of class UINT The attribute ID number of the -
attributes last class attribute of the class
definition implemented in the
device
7 Get Max ID number of instance UINT The attribute ID number of the -
attributes last instance attribute of the
class definition implemented in
the device

Instance attributes

Attribute Access Name Data type Description Semantics

ID of values
1 Set Open requests UINT Number of forward open service requests received -

2 Set Open format rejects UINT Number of forward open service requests which -
were rejected due to bad format

3 Set Open resource rejects UINT Number of forward open service requests which -
were rejected due to lack of resources

4 Set Open other rejects UINT Number of forward open service requests which -
were rejected for reasons other than bad format or
lack of resources
5 Set Close requests UINT Number of forward close service requests received -

6 Set Close format rejects UINT Number of forward close service requests which -
were rejected due to bad format

7 Set Close other rejects UINT Number of forward close service requests which -
were rejected for reasons other than bad format

8 Set Connection timeouts UINT Total number of connection timeouts that have -
occurred in connections controlled by this
connection manager

Supported class and instance services

Class service code Instance service Service name Description

code
01 hex 01 hex Get_Attribute_All Return all attributes

0E hex 0E hex Get_Attribute_Single Return single attribute

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Supported class and instance services (Continued)

Class service code Instance service Service name Description

code
– 54 hex Forward_Open Opens a connection

– 4E hex Forward_Close Closes a connection

TCP/IP interface object (F5 hex)

Class attributes

Attribute ID Access Name Data type Description Semantics of values

1 Get Revision UINT Revision of this object The current value assigned to
this attribute is one (01). If
updates that require an
increase in this value are
made, then the value of this
attribute increases by 1

2 Get Max instances UINT Maximum instance number of The largest instance number
an object currently created in of a created object at this
this class level of the device class hierarchy level

3 Get Number of instances UINT Number of object instances The number of object
currently created at this class instances at this class
level of the device hierarchy level

Instance attributes

Attribute Access Name Data type Description Semantics of values

ID
1 Get Status DWORD Interface status Bit 0-3: Indicates the status of the interface
configuration attribute
• 0 = The interface configuration attribute
has not been configured
1 = The interface configuration attribute
contains configuration obtained from
BOOTP, DHCP or non-volatile storage
2 = The IP address member of the
interface configuration attribute contains
configuration, obtained from hardware
settings
3-15 = Reserved for future use
2 Get Configuration DWORD Interface capability Bit 0: 1 (TRUE) shall indicate the device is
capability flags capable of obtaining its network configuration
via BOOTP

Bit 1: 1 (TRUE) shall indicate the device is

capable of resolving host names by querying
a DNS server

Bit 2: 1 (TRUE) shall indicate the device is

capable of obtaining its network configuration
via DHCP

Bit 3: Shall be 0, behavior to be defined in a

future specification edition

Bit 4: 1 (TRUE) shall indicate the interface

configuration attribute is settable

Bit 5: 1 (TRUE) shall indicate the IP address

member of the interface configuration
attribute can be obtained from hardware
settings

Bit 6: 1 (TRUE) shall indicate that the device

requires a restart in order for a change to the
interface configuration attribute to take effect

Bit 7: 1 (TRUE) shall indicate that the device

is ACD capable

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Instance attributes (Continued)

Attribute Access Name Data type Description Semantics of values

ID

Bit 8-31: Reserved for future use and shall be

set to zero
3 Get Configuration control DWORD Interface control flags Bit 0-3: Determines how the device shall
obtain its IP-related configuration
• 0 = The device shall use statically-
assigned IP configuration values
1 = The device shall obtain its interface
configuration values via BOOTP
2 = The device shall obtain its interface
configuration values via DHCP
3-15 = Reserved for future use
Bit 4: 1 (TRUE) shall resolve host names by
querying a DNS server

Bit 5-31: Reserved for future use and shall be

set to zero
4 Get Physical link object STRUCT Path to physical link This attribute identifies the object associated
of: object with the underlying physical communications
interface
Path size UINT Size of path Number of 16 bit words in path

Path Padded Logical segments The path is restricted to one logical class
EPATH identifying the physical segment and one logical instance segment.
link object The maximum size is 12 bytes

5 Get Interface configuration STRUCT TCP/IP network The interface configuration attribute contains
of: interface configuration the configuration parameters required for a
device to operate as a TCP/IP node. The
contents of the interface configuration
attribute shall depend upon how the device
has been configured to obtain its IP
parameters

IP address UDINT The device’s IP Value of 0 indicates no IP address has been

address configured. Otherwise, the IP address shall
be set to a valid class A, B, or C address and
shall not be set to the loopback address
(127.0.0.1)

Network mask UDINT The device’s network Value of 0 indicates no network mask address
mask has been configured

Gateway address UDINT Default gateway Value of 0 indicates no IP address has been
address configured. Otherwise, the IP address shall
be set to a valid class A, B, or C address and
shall not be set to the loopback address
(127.0.0.1)

Name server UDINT Primary name server Value of 0 indicates no name server address
has been configured. Otherwise, the name
server address shall be set to a valid class A,
B, or C address

Name server 2 UDINT Secondary name server Value of 0 indicates no secondary name
server address has been configured.
Otherwise, the name server address shall be
set to a valid class A, B, or C address

Domain name STRING Default domain name ASCII characters. Maximum length is 48
characters. Shall be padded to an even
number of characters (pad not included in
length). A length of 0 shall indicate no domain
name is configured

6 Get Host name STRING Host name ASCII characters. Maximum length is 64
characters. Shall be padded to an even
number of characters (pad not included in
length). A length of 0 shall indicate no host
name is configured

13 Set Encapsulation UINT Number of seconds of 0 = Disable

inactivity timeout inactivity before TCP
connection or DTLS 1-3600 = timeout in seconds
session is closed
Default = 120

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Supported class and instance services

Class service Instance service Service name Description

code code
– 01 hex Get_Attribute_All Return all attributes

0E hex 0E hex Get_Attribute_Single Return single attribute

– 10 hex Set_Attribute_Single Write one attribute

Ethernet link object (F6 hex)

Class attributes

Attribute Access Name Data type Description Semantics of values

ID
1 Get Revision UINT Revision of this object The current value assigned
to this attribute is one (01).
If updates that require an
increase in this value are
made, then the value of this
attribute increases by 1

2 Get Max instances UINT Maximum instance number of an The largest instance
object currently created in this number of a created object
class level of the device at this class hierarchy level

3 Get Number of instances UINT Number of object instances The number of object
currently created at this class instances at this class
level of the device hierarchy level

4 Get Optional attribute list STRUCT of: List of optional instance A list of attribute numbers
attributes utilized in an object specifying the optional
class implementation attributes implemented in
the device for this class
Number of attributes UINT Number of attributes in the The number of attribute
optional attribute list numbers in the list

Optional attributes ARRAY of UINT List of optional attribute numbers The optional attribute
numbers
6 Get Max ID number of class UINT The attribute ID number of the -
attribute last class attribute of the class
definition implemented in the
device
7 Get Max ID number of UINT The attribute ID number of the -
instance attribute last instance attribute of the class
definition implemented in the
device

Instance attributes

Attribute Access Name Data type Description Semantics of values

ID
1 Get Interface speed UDINT Interface speed currently in Speed in Mbps
use
2 Get Interface flags DWORD Interface status flags Bit 0: Link status indicates whether the IEEE
802.3 communications interface is connected
to an active network. 0 indicates an inactive
link; 1 indicates an active link

Bit 1: Half/Full duplex indicates the duplex

mode currently in use. 0 indicates that the
interface is running half duplex; 1 indicates full
duplex

Bit 2-4: Negotiation status

• 0 = Auto-negotiation in progress
• 1 = Auto-negotiation and speed detection
failed
• 2 = Auto negotiation failed but speed
detected
• 3 = Successfully negotiated speed and
duplex

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Instance attributes (Continued)

Attribute Access Name Data type Description Semantics of values

ID
• 4 = Auto-negotiation not attempted
Bit 5: Manual setting requires reset

Bit 6: 0 indicates the interface detects no local

hardware fault; 1 indicates a local hardware
fault is detected

Bit 7-31: Reserved shall be set to zero

3 Get Physical Array of 6 MAC layer address The recommended display format is "XX-XX-
address USINTs XX-XX-XX-XX", starting with the first octet

7 Get Interface type USINT Type of interface: twisted Value 0: Unknown interface type
pair, fiber, internal
Value 1: The interface is internal to the device

Value 2: Twisted-pair

Value 3: Optical fiber

Value 4-255: Reserved

8 Get Interface state USINT Current state of the Value 0: Unknown interface state
interface: operational,
disabled Value 1: The interface is enabled and is ready
to send and receive data

Value 2: The interface is disabled

Value 3: The interface is testing

Value 4-255: Reserved

10 Get Interface label SHORT_ Human readable The interface label attribute shall be a text
STRING identification string that describes the interface. The content
of the string is vendor specific.

11 Get Interface STRUCT of: Indication of capabilities of Bit 0: Manual setting requires reset
capability the interface • 0 = Indicates that the device
automatically applies changes made to
the interface control attribute and,
therefore, does not require a reset in
order for changes to take effect.
• 1 = Indicates that the device does not
automatically apply changes made to the
interface control attribute and, therefore,
will require a reset in order for changes to
take effect.
Bit 1: Auto-negotiate
• 0 = Indicates that the interface does not
support link auto-negotiation
• 1 = Indicates that the interface supports
link auto-negotiation
Bit 2: Auto-MDIX
• 0 = Indicates that the interface does not
support auto MDIX operation
• 1 = Indicates that the interface supports
auto MDIX operation
Bit 2: Manual speed/duplex
• 0 = Indicates that the interface does not
support manual setting of speed/duplex.
The interface control attribute shall not be
supported
• 1 = Indicates that the interface supports
manual setting of speed/duplex via the
interface control attribute
Bit 4-31: Reserved. Shall be set to 0
Capability bits DWORD Interface capabilities, other Bitmap
than speed/duplex

Speed/Duplex STRUCT of: Indicates speed/duplex pairs -

options supported in the interface
control attribute

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Instance attributes (Continued)

Attribute Access Name Data type Description Semantics of values

ID
USINT Speed/Duplex array count Number of elements

ARRAY of Speed/Duplex array -

STRUCT of:
UINT Interface speed Speed in Mbps

USINT Interface duplex mode 0 = Half duplex

1 = Full duplex

2-255 = Reserved

Supported class and instance services

Service code Service name Description

01 hex Get_Attribute_All Return all attributes

0E hex Get_Attribute_Single Return single attribute

Port object (F4 hex)

Class code

Hexadecimal Decimal
F4 hex 299

Class attributes

Attribute Access Name Data type Description Semantics of values

ID
1 Get Revision UINT Revision of this object The current value assigned to
this attribute is one (01). If
updates that require an
increase in this value are
made, then the value of this
attribute increases by 1

2 Get Max instance UINT Maximum instance number of The largest instance number
an object currently created in of a created object at this
this class level of the device class hierarchy level

3 Get Number of instances UINT Number of object instances The number of object
currently created at this class instances at this class
level of the device hierarchy level

8 Get Entry port UINT Returns the instance of the 1

port object that describes the
port through which this
request entered the device

9 Get Port instance info ARRAY of Array of structures containing The array is indexed by
instance attributes 1 and 2 instance number starting with
STRUCT of from each instance zero, up to the maximum
instance number. The values
for instance zero and any
non-instantiated instances
shall be zero
Port type UINT Enumerates the type of port The vendor assigns values to
these three attributes to
indicate the type of the port,
whether or not it supports
routing, and whether it
provides a link specific object
to make link specific
functionality visible to CIP

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Class attributes (Continued)

Attribute Access Name Data type Description Semantics of values

ID
Port number UINT CIP port number associated Manufacturer assigns a
with this port unique value to identify each
communication port. Value 0
is reserved and cannot be
used

Instance attributes

Attribute Access Name Data type Description Semantics of values

ID
1 Get Port type UINT Enumerates the type of port The vendor assigns value to this
attribute to indicate the type of port

2 Get Port number UINT CIP port number associated with Manufacturer assigns a unique
this port value to identify each
communication port. Value 0 is
reserved and cannot be used
3 Get Link object STRUCT of: The vendor assigns value to this
attribute to indicate whether it
Path length UINT Number of 16 bit words in the path supports routing, and whether it
provides link specific object to make
Link path Padded EPATH Logical path segments that identify link specific functionality visible to
the object for this port CIP

4 Get Port name SHORT_ String which names the This attribute is the vendor assigned
STRING communications interface. The name of the communications
maximum number of characters in interface associated with this
the string is 64 instance

7 Get Port number Padded EPATH Port segment containing the port The port number and node address
and node number and the link address of the value shall be a port segment
address device on this port containing the port number of this
port and the link address of this
device on the port

10 Get Port routing DWORD Bit string that defines the routing Bit 0: Routing of incoming
capabilities capabilities of this port unconnected messaging supported

Bit 1: Routing of outgoing

unconnected messaging supported

Bit 2: Routing of incoming transport

class 0/1 connections supported

Bit 3: Routing of outgoing transport

class 0/1 connections supported

Bit 4: Routing of incoming transport

class 2/3 connections supported

Bit 5: Routing of outgoing transport

class 2/3 connections supported

Bit 6: Routing of outgoing DeviceNet

CIP safety connections supported

Bit 7-31: Reserved

Supported class and instance services

Service code Service Name Description

0x0E Get_Attribute_Single Used to read a port class attribute value. This service is
required if any of the port class attributes are supported

Base energy object (4E hex)

Class code

Hexadecimal Decimal
4E hex 78

104 HRB1684301-12
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Class attributes

Attribute ID Access Name Data type Description Semantics of values

1 Get Revision UINT Revision of this object The current value

assigned to this attribute
is two (2)

Instance attributes

Attribute Access Name Data type Description Semantics of values

ID
1 Get Energy/resource UINT Specifies the type of energy 0: Generic
type managed by this energy
instance 1: Electrical

2: Non-electrical

3-99: Reserved

100-199: Vendor specific

200-65535: Reserved
2 Get Base energy object UINT The energy capabilities of the 0: Energy measured
capabilities instance
1: Energy derived

2: Energy proxy

3: Energy aggregated

4: Energy rate fixed

5: Non-electrical aggregated

6-65535: Reserved
3 Get Energy accuracy UINT Specifies the accuracy of Typical accuracy in 0.01
power and energy metering percent of reading (default) or
results 0.01 of other units as
specified in the energy
accuracy basis attribute

0: Unknown
7 Get Consumed energy ODOMETER The consumed energy value Energy in kWh
odometer
8 Get Generated energy ODOMETER The generated energy value Energy in kWh
odometer
9 Get Net energy odometer SIGNED_ The total net energy value Energy in kWh
ODOMETER
10 Get Energy transfer rate REAL The time rate of energy Power in kW
consumption or production

12 Get Energy type specific STRUCT of: Path to energy type specific This attribute may contain a
object path object instance path to an electrical energy
object instance (class code
0x4F), a path to a non-
electrical energy object
instance (class code 0x50) or
a null path (a path size value
of zero (0))

Path size UINT Size of Path (in words) -

Path Padded EPATH - -

Supported class and instance services

Service code Service name Description

0E hex Get_Attribute_Single Used to read a base energy class attribute value

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PowerLogic™ PM5500 / PM5600 / PM5700 series Communications

Odometer and Signed_Odometer structure principle

Data type structure Description of data type element Semantics of values

ODOMETER STRUCT SIGNED_ODOMETER – –

of: STRUCT of:
UINT INT x10n ±Unit x 10n
UINT INT x10n+3 ±Unit x 10n+3
UINT INT x10n+6 ±Unit x 10n+6
UINT INT x10n+9 ±Unit x 10n+9
UINT INT x10n+12 ±Unit x 10n+12
The valid range of n shall be a SINT between 0 and -15.

Odometer type in kilowatt-hour units and n = -3

x10n+12 x10n+9 x10n+6 x10n+3 x10n

Terawatt-hours Gigawatt-hours Megawatt-hours Kilowatt-hours (kWh) Watt-hours
(kWh x 109) (kWh x 106) (kWh x 103) (kWh x 10-3)

Electrical energy object (4F hex)

Class code

Hexadecimal Decimal
4F hex 79

Class attributes

Attribute ID Access Name Data type Description Semantics of values

1 Get Revision UINT Revision of this object The current value

assigned to this attribute
is two (2)

Instance attributes

Attribute Access Name Data type Description Semantics of values

ID
1 Get Real energy consumed ODOMETER The total real energy 0 kWh to
odometer consumed 999,999,999,999.999 kWh

2 Get Real energy generated ODOMETER The total real energy 0 kWh to
odometer generated 999,999,999,999.999 kWh

3 Get Real energy net odometer SIGNED_ The running total of real -999,999,999,999.999 kWh
ODOMETER energy consumed minus to 999,999,999,999.999
real energy generated kWh

4 Get Reactive energy ODOMETER The total reactive power 0 kVARh to

consumed odometer consumed 999,999,999,999.999
kVARh
5 Get Reactive energy ODOMETER The total reactive power 0 kVARh to
generated odometer generated 999,999,999,999.999
kVARh
6 Get Reactive energy net SIGNED_ The running total of reactive -999,999,999,999.999
odometer ODOMETER energy consumed minus kVARh to
reactive energy generated 999,999,999,999.999
kVARh
7 Get Apparent energy ODOMETER The total apparent energy Range from 0 kVAh to
odometer consumed 999,999,999,999.999 kVAh

9 Get Line frequency REAL Line Frequency in Hertz Hz

10 Get L1 current REAL RMS line current in L1 Amps (A)

11 Get L2 current REAL RMS line current in L2 Amps (A)

12 Get L3 current REAL RMS line current in L3 Amps (A)

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Instance attributes (Continued)

Attribute Access Name Data type Description Semantics of values

ID
13 Get Average current REAL RMS line current of three- Amps (A)
phase average

14 Get Percent current REAL Percentage current Percent

unbalance deviation between phases

15 Get L1-N voltage REAL RMS line to neutral voltage Volts (V)
of L1
16 Get L2-N voltage REAL RMS line to neutral voltage Volts (V)
of L2
17 Get L3-N voltage REAL RMS line to neutral voltage Volts (V)
of L3
18 Get Average L-N voltage REAL RMS line to neutral voltage Volts (V)
of three-phase average

19 Get L1-L2 voltage REAL RMS L1 to L2 voltage Volts (V)

20 Get L2-L3 voltage REAL RMS L2 to L3 voltage Volts (V)

21 Get L3-L1 voltage REAL RMS L3 to L1 voltage Volts (V)

22 Get Average L-L voltage REAL RMS line to line voltage Volts (V)
three-phase average

23 Get Percent voltage REAL Percentage voltage Percent

unbalance deviation between phases

24 Get L1 real power REAL L1 real power, signed to Watts (W)

show direction
25 Get L2 real power REAL L2 real power, signed to Watts (W)
show direction
26 Get L3 real power REAL L3 real power, signed to Watts (W)
show direction
27 Get Total real power REAL Total real power, signed to Watts (W)
show direction
28 Get L1 reactive power REAL L1 reactive power, signed to Volt-amps reactive (VAR)
show direction
29 Get L2 reactive power REAL L2 reactive power, signed to Volt-amps reactive (VAR)
show direction
30 Get L3 reactive power REAL L3 reactive power, signed to Volt-amps reactive (VAR)
show direction
31 Get Total reactive power REAL Total reactive power, signed Volt-amps reactive (VAR)
to show direction
32 Get L1 apparent power REAL L1 apparent power Volt-amps (VA)

33 Get L2 apparent power REAL L2 apparent power Volt-amps (VA)

34 Get L3 apparent power REAL L3 apparent power Volt-amps (VA)

35 Get Total apparent power REAL Total apparent power Volt-amps (VA)

36 Get L1 true power factor REAL L1 ratio between power and Percent
apparent power

37 Get L2 true power factor REAL L2 ratio between power and Percent
apparent power

38 Get L3 true power factor REAL L3 ratio between power and Percent
apparent power

39 Get Three phase true power REAL Ratio between power and Percent
factor apparent power

40 Get Phase rotation UINT The phase rotation of a 0 = None

three-phase system
1 = ABC

2 = ACB
41 Get Associated base energy STRUCT of: Path to associated base 03 00 21 00 4E 00 24 01
object path energy object instance

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Instance attributes (Continued)

Attribute Access Name Data type Description Semantics of values

ID
Path size UINT Size of path (in words)

Path Padded EPATH -

Class and instance services

Service code Service name Description

0E hex Get_Attribute_Single Used to read a electrical energy class attribute value

DNP3
The DNP3 over Ethernet is available in firmware version 10.7.1 and above for
PM5561 / PM5661 / PM5761 meter models and firmware version 2.7.4 and above
for all the other meter models except PM5562 / PM5562MC.
The Distributed Network Protocol Version 3.0 (DNP3) is a multipoint
communication protocol which specifies the coding of data and rules for
exchanging the data between a slave device and a master control device. DNP3 is
an open protocol which can be implemented on any communication device. The
DNP3 is available on Ethernet communication.
The DNP3 protocol specifies the data that can be exchanged and the form in
which they are transmitted.

DNP3 device profile

The meter can be integrated into a DNP network as a DNP slave (pre-configured
for basic DNP slave functionality).
The meter supports a maximum of three concurrent connections (sessions) using
the DNP3 protocol.
The DNP3 is disabled by default. You can modify the meter’s default DNP3
settings using webpages and HMI. The data can be imported into the meter from a
DNP control relay or an analog output device.
The primary objects of the DNP3 are as follows:
• Analog input
• Binary counter
• Binary input

DNP3 device profile document

Vendor name: Schneider Electric

Device name: PM5XXX
Highest DNP level supported: Device function:

For requests: Level 2 Master

For responses: Level 2 Slave

For static (non-change-event) object requests, request qualifier codes 07 and 08 (limited quantity), and 17 and 28 (index) are supported.
Static object requests sent with qualifiers 07 or 08 are responded with qualifiers 00 or 01.

16-bit, 32-bit and floating point functions are supported.

Maximum data link frame size (octets): Maximum application fragment size (octets):

Transmitted: 292 Transmitted: 50 to 248

Received: 292 Received: 2048

Maximum data link re-tries: Maximum application layer re-tries:

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DNP3 device profile document (Continued)

None None

Fixed Configurable

Requires data link layer confirmation:

Never

Always

Sometimes
Requires application layer confirmation:

Never

Always

When reporting event data (Slave devices only)

Sometimes
Timeouts while waiting for:

Data link confirm: None Fixed at ____ Variable Configurable

Complete appl. fragment: None Fixed at ____ Variable Configurable

Application confirm: None Fixed at 10 s Variable Configurable

Complete appl. response: None Fixed at ____ Variable Configurable

Sends/Executes control operations:

WRITE binary outputs: Never Always Sometimes Configurable

SELECT/OPERATE: Never Always Sometimes Configurable

DIRECT OPERATE: Never Always Sometimes Configurable

DIRECT OPERATE – NO ACK: Never Always Sometimes Configurable

Count > 1 Never Always Sometimes Configurable

Pulse on Never Always Sometimes Configurable

Pulse off Never Always Sometimes Configurable

Latch on Never Always Sometimes Configurable

Latch off Never Always Sometimes Configurable

Queue Never Always Sometimes Configurable

Clear queue Never Always Sometimes Configurable

Attach explanation if 'Sometimes' or 'Configurable' was checked for any operation.

Reports binary input change events when no specific variation Reports time-tagged binary input change events when no specific
requested: variation requested:

Never Never

Only time-tagged Binary input change with time

Only non-time-tagged Binary input change with relative time

Sends unsolicited responses: Sends static data in unsolicited responses:

Never Never

Configurable - enable/disable When device restarts

Only certain objects When status flags changes

Sometimes (attach explanation) No other options are permitted

ENABLE/DISABLE UNSOLICITED function codes supported

Default counter object/variation: Counters roll over at:

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DNP3 device profile document (Continued)

No counters reported No counters reported

Configurable Configurable

Default object 16 bits

Default variation 32 bits

Point-by-point list attached Other value____

Point-by-point list attached

Sends multi-fragment responses:

Yes

No
Sequential file transfer support:

Append file mode Yes No

Custom status code strings Yes No

Permissions field Yes No

File events assigned to class Yes No

File events send immediately Yes No

Multiple blocks in a fragment Yes No

Max number of files open 0

DNP3 implementation objects

Object Request (Slave must parse) Response (Master must parse)

Objects Variation Description Functional Qualifier codes Functional Qualifier codes

codes (dec) (hex) codes (dec) (hex)

1 0 Binary input - Any 1 00,01,06,07,08,17,28 - -

variation
1 1 Binary input 1 00,01,06,07,08,17,28 129 00,01,17,28

1 2 Binary input with status 1 00,01,06,07,08,17,28 129 00,01,17,28

20 0 Binary counter - Any 1 00,01,06,07,08,17,28 - -

variation
7,8 0,01,06,07,08 - -

20 1 32-bit binary counter 1 00,01,06,07,08,17,28 129 00,01,17,28

20 2 16-bit binary counter 1 00,01,06,07,08,17,28 129 00,01,17,28

20 5 32-bit binary counter 1 00,01,06,07,08,17,28 129 00,01,17,28

without flag

20 6 16-bit binary counter 1 00,01,06,07,08,17,28 129 00,01,17,28

without flag

30 4 16-bit analog input 1 00,01,06,07,08,17,28 129 00,01,17,28

without flag

30 5 Short floating point 1 00,01,06,07,08,17,28 129 00,01,17,28

30 6 Long floating point 1 00,01,06,07,08,17,28 129 00,01,17,28

50 0 Time and date - Any - - - -

variation
50 1 Time and date 1 00,01,06,07,08 129 00,01,17,28

2 07, quantity = 1 - -

52 0 Time delay - All - - - -

variations
52 1 Time delay coarse - - 129 07, quantity = 1

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Object Request (Slave must parse) Response (Master must parse)

Objects Variation Description Functional Qualifier codes Functional Qualifier codes

codes (dec) (hex) codes (dec) (hex)

52 2 Time delay fine - - 129 07, quantity = 1

60 0 Not defined - - - -

60 1 Class 0 data 1 06,07,08 - -

60 2 Class 1 data 1 06,07,08 - -

60 3 Class 2 data 1 06,07,08 - -

60 4 Class 3 data 1 06,07,08 - -

Default DNP3 configuration

Analog input objects

16-bit analog input without flag (Object 30, Variation 4)

Point Measurement
0 Vln a
1 Vln b
2 Vln c
3 Vln avg

4 Vll ab
5 Vll bc
6 Vll ca
7 Vll avg

8 Ia
9 Ib
10 Ic
11 I avg

12 kW a
13 kW b
14 kW c
15 kW tot
16 kVAR a
17 kVAR b
18 kVAR c
19 kVAR tot
20 kVA a
21 kVA b
22 kVA c
23 kVA tot
24 PFsign a

25 PFsign b

26 PFsign c

27 PFsign tot

28 V unbal (Voltage unbalance L-L worst)

29 I unbal (Current unbalance worst)

30 I4

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16-bit analog input without flag (Object 30, Variation 4)

Point Measurement
31 Freq

32 kW sd del-rec2
33 kVAR sd del-rec3
34 kVA sd del+rec3
35* I5
36* I6
37* A1 Raw value
38* A1 Scaled value
39* A2 Raw value
40* A2 Scaled value
*Available in specific meter models. Refer to Features
differentiation matrix for PM5500 / PM5600 / PM5700 series,
page 20 for the availability.

Binary counter objects

16-bit binary counter without flag (Object 20, Variation 6)

Point Measurement
0 kWh del (Import)

1 kWh rec (Export)

2 kWh del+rec (Total)

3 kWh del-rec (Net)

4 kVARh del (Import)

5 kVARh rec (Export)

6 kVARh del+rec (Total)

7 kVARh del-rec (Net)

8 kVAh del+rec (Total)

Binary input objects

16-bit binary input without flag (Object 1)

Point Measurement
0 Digital input 1

1 Digital input 2

2 Digital input 3*

3 Digital input 4*

4 Digital output 1

5 Digital output 2

*Available in specific meter models. Refer to Features

differentiation matrix for PM5500 / PM5600 / PM5700 series,
page 20 for the availability.

Configuring DNP3 setting using the display

The Ethernet setup screen on the meter allows you to configure DNP3
communication.

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1. Navigate to Maint > Setup.

2. Enter the setup passcode (default is “0”), then press OK.
3. Navigate to Comm > Enet.
4. Move the cursor to point to the parameter DNP3 you want to modify, then
press Edit.
5. Modify the parameter as required (Enabled/Disabled), then press OK.
6. Press the up arrow to exit.
7. Press Yes to save your changes.

Configuring DNP3 setting using the webpages

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
You can use the meter’s webpages to configure DNP3 settings.
1. Login to the meter webpages.
2. Based on your meter firmware version, click Settings > DNP3 Settings OR
click Settings > Communication > DNP3 Settings.
3. Click Yes to enable DNP3 or click No to disable DNP3 as required.
4. Click Save changes or Apply Changes to send and save the new settings to
the meter.

Modbus Ethernet gateway

A Modbus Ethernet gateway allows multiple Modbus masters on the LAN/WAN to
connect to downstream serial Modbus slave devices.
A Modbus master device, such as an energy management system, can
communicate through the gateway meter to a serial network of devices connected
to the gateway meter’s serial port(s). The meter receives Modbus TCP/IP data on
TCP port 502, translates it to Modbus RTU then forwards it to the addressed slave
device.
This functionality allows the use of monitoring software to access information from
slave devices for data collection, trending, alarm/event management, analysis,
and other functions.

Ethernet gateway implementation

There is specific implementation information to consider when using your meter as
an Ethernet gateway.

Firmware support
The Ethernet gateway functionality is available on firmware version 2.0.1 or later.

Addressing
You can use slave address 255 or the Unit ID configured in the gateway meter’s
serial settings to send a request to the gateway-enabled meter itself. Messages
addressed with other unit IDs are forwarded by the gateway meter to the RS-485
slave devices.

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Broadcast messages
The gateway meter always processes broadcast messages (in other words,
messages sent to Unit ID 0). You can configure whether or not broadcast
messages are forwarded to the slave devices.

Modbus master TCP/IP connections

The maximum number of Modbus master TCP connections allowed for the
Ethernet gateway is configurable. It is the same as the maximum number of total
Modbus TCP/IP connections that are configured on the gateway-enabled meter.

Ethernet gateway configuration

Configuring the meter as an Ethernet gateway using the

webpages
NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
The meter can function as an Ethernet gateway, allowing Ethernet access to serial
devices connected to the meter’s RS-485 serial communications port.
You must install the serial Modbus slave devices, configure them and connect
them to your Ethernet-connected Modbus gateway meter. Ensure that each serial
device is configured to communicate over Modbus with the same baud rate and
parity as the gateway device, and that each device, including the gateway, has a
unique unit ID.
The only configuration required for the meter to function as a gateway is to set the
serial port’s mode. You can configure other settings, depending on your
requirements and network.
NOTE: The protocol of the serial port must be set to Modbus RTU or Jbus for
the meter to function as a gateway.
1. Login to the meter webpages.
2. Based on your meter firmware version, click Settings > Serial Settings OR
click Settings > Communication > Serial Port Configuration.
3. Set Mode to Gateway to enable the gateway feature or to Slave to disable it.
4. Set Modbus Broadcast to Enabled if you want broadcast messages to be
forwarded to the connected slave devices.
5. Configure the other advanced parameters required by your system.

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6. Based on your meter firmware version, navigate to Settings > Advanced

Ethernet Settings OR navigate to Settings > Communication > Advanced
Ethernet Settings and change the Modbus TCP/IP Server Connections to
adjust the maximum number of Modbus TCP connections allowed.

Modbus Ethernet gateway settings available using the webpages

Parameter Value Description

Response Timeout 0.1, 0.2, 0.3, 0.4, 0.5, 1, 2, 3, 4, Set the time the gateway meter waits for an answer from a
5, 6, 7, 8, 9, 10 downstream serial device before generating an exception response.

Delay Between Frames 0, 10, 20, 30, 40, 50, 60, 70, 80, The minimum time in milliseconds between the end of a received
90, 100 response and the beginning of a new request.

Set this parameter to help improve communications between the

gateway and downstream slave devices with slower response
times.
Silent Interval Extension 0 – 15 Set this parameter to extend the silent interval (used to mark the
end of a Modbus packet) beyond the default 3.5 characters defined
in the Modbus standard. After the defined character time elapses
without a new character, the gateway meter treats the next
character as the start of a new message.

NOTE: These are advanced settings that you can adjust if you have
communication errors when communicating through the gateway to the
downstream serial devices. They only apply if the meter is functioning as
a gateway, and you should only change these settings if you have an
advanced knowledge of Modbus communications and your
communications network.

Configuring the meter as an Ethernet gateway using ION Setup

The meter can function as an Ethernet gateway, allowing Ethernet access to serial
devices connected to the meter’s RS-485 serial communications port.
You must install the serial Modbus slave devices, configure them and connect
them to your Ethernet-connected Modbus gateway meter. Ensure that each serial
device is configured to communicate over Modbus with the same baud rate and
parity as the gateway device, and that each device, including the gateway, has a
unique unit ID.
The only configuration required for the meter to function as a gateway is to set the
serial port’s mode. You can configure other settings, depending on your
requirements and network.
NOTE: The protocol of the serial port must be set to Modbus RTU or Jbus for
the meter to function as a gateway.
1. Start ION Setup and connect to your meter.
2. Open the Advanced Serial Settings screen in the RS-485 Comm Setup
folder.
3. Set Mode to Master Mode to enable the gateway feature or to Slave Mode to
disable it.
4. Set Modbus Broadcast to Enabled if you want broadcast messages to be
forwarded to the connected slave devices.
5. Configure the other advanced parameters required by your system.
6. Click Send to save your changes to the meter.

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7. Use the meter webpages if you want to adjust the maximum number of
Modbus TCP connections allowed.
Modbus Ethernet gateway settings available using ION Setup

Parameter Value Description

Response Timeout 0.1, 0.2, 0.3, 0.4, 0.5, Set the time the gateway meter waits for an
1, 2, 3, 4, 5, 6, 7, 8, answer from a downstream serial device
9, 10 before generating an exception response.

Delay Between 0, 10, 20, 30, 40, 50, The minimum time in milliseconds between
Frames 60, 70, 80, 90, 100 the end of a received response and the
beginning of a new request.

Set this parameter to help improve

communications between the gateway and
downstream slave devices with slower
response times.

Silent Interval 0 – 15 Set this parameter to extend the silent

Extension interval (used to mark the end of a Modbus
packet) beyond the default 3.5 characters
defined in the Modbus standard. After the
defined character time elapses without a new
character, the gateway meter treats the next
character as the start of a new message.

NOTE: These are advanced settings that you can adjust if you have
communication errors when communicating through the gateway to the
downstream serial devices. They only apply if the meter is functioning as
a gateway, and you should only change these settings if you have an
advanced knowledge of Modbus communications and your
communications network.

Modbus TCP/IP filtering

The Modbus TCP/IP filtering feature lets you specify the access rights to the
meter, using Modbus communications, for specified IP addresses plus the access
rights for anonymous IP addresses.
This feature determines the access to the meter and any downstream serial
devices if the meter is functioning as a Modbus gateway.

Modbus TCP/IP filtering implementation

You can specify the Modbus access rights for up to 10 unique IP addresses and
for anonymous IP addresses.
By default, Modbus TCP/IP filtering is disabled and all IP addresses have full
access to the meter and any downstream serial devices.

Access levels
You can set the level of access for each configured IP address, as well as for
anonymous IP addresses.

Access level Description

Read-only This setting allows only the following function codes to be sent to the meter and any downstream
serial devices from the specified IP address: 01 (0x01), 02 (0x02), 03 (0x03), 04 (0x04),
07 (0x07), 08 (0x08), 11 (0x0B), 12 (0x0C), 17 (0x11), 20 (0x14), 24 (0x18), 43 (0x2B) and
100 (0x64)

Full This setting allows any Modbus function code to be sent to the meter and any downstream serial
devices from the specified IP address.

None This setting denies access to anonymous IP addresses.

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Configuring Modbus TCP/IP filtering using the webpages

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
You can configure access rights for any valid IP address, plus any anonymous IP
addresses.
1. Login to the meter webpages.
2. Based on your meter firmware version, click Settings > Modbus TCP/IP
filtering OR click Settings > Communication > IP filtering.
3. Click Enable Filtering to enable Modbus TCP/IP filtering.
The IP address fields become editable, except for the anonymous IP address
field, which is indicated by asterisks (***.***.***.***).
4. Set the access for anonymous IP addresses.
NOTE: If Modbus TCP/ IP filtering is enabled, anonymous IP addresses
can only have read-only or no access; they cannot have full access.
5. Enter the other IP addresses that you want to be able to access the meter
and any downstream serial devices.
6. Set the access level for each specified IP address.
NOTE: If duplicate IP addresses are entered, the second listing and its
access level are discarded when you save the changes.

Simple Network Management Protocol (SNMP)

Your meter supports SNMP once you have enabled SNMP on your meter. You
need to upload the meter’s MIB file (available from www.se.com) into the NMS
managing your meter.
Simple Network Management Protocol (SNMP) is part of the Transmission Control
Protocol/Internet Protocol (TCP/IP) protocol suite. SNMP is an application layer
protocol that enables the exchange of network management information between
devices, allowing you to manage network performance and to identify and solve
problems on networks with devices of various types.
SNMP configuration assumes that you have an advanced understanding of SNMP
and the communications network and power system that your meter is connected
to.

Key terms

Term Definition
Agent Software resident on the managed device which interfaces between the
device and the NMS.
Managed device Your meter in the SNMP network.

Community name/ A text string that helps authenticate requests between the managed
string device and the NMS.

Managed object Any parameter referenced in the MIB file.

MIB A management information base which organizes the OIDs in a

hierarchical tree.
NMS A network management station, manager or client that executes
applications to monitor and control devices. An NMS must have the
standard and custom MIB files and SNMP manager software.

OID An object identifier that uniquely identifies and labels a managed object in
the MIB.
Trap receiver An NMS that is configured to receive traps and whose IP address is an
SNMP trap destination.

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The meter in an SNMP system

Your meter is a managed device with an SNMP agent in an SNMP network.

A. Trap receiver(s)
B. SNMP agent (meter)
C. NMS with SNMP manager software and MIB file installed

NOTE: The NMS computer can also function as a trap receiver.

SNMP implementation
Your meter supports SNMP after you upload the meter’s MIB file into the NMS
managing your meter.
By default, SNMP communication is enabled and SNMP trapping is disabled. Use
the meter’s webpages to enable / disable SNMP and configure SNMP
parameters.

Supported requests
Your meter supports get and get-next requests (read-only).

MIB file
The MIB file is a human-readable text file. Besides being required by your NMS,
you can use it to determine the objects the meter supports and their object IDs.
SNMP requires that you load your meter’s MIB file (available for download from
www.se.com) into the NMS. The MIB filename is SchneiderPM5xxx_Vyy_zz.MIB,
where yy is the major revision and zz is the minor revision.
Your meter is compliant with MIB-II as defined by the standard MIB file RFC 1213.
You must install RFC 1213, which is required to read basic network information for
the meter (for example, TCP/IP traffic or number of packets received), if it is not
included with your SNMP manager software.

Community names
A community name is a text string which acts to help authenticate requests from
the NMS to your meter. There are two configurable community names on your
meter:
• Read-only Community: this community name’s initial factory-set value is
public.

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• Read-write Community: this community name’s initial factory-set value is

private.
If your meter receives an incorrect community string, it generates an
AuthenticationFailure trap.

System variables
A system variable is a text string which can be configured to provide information
about your meter. There are three system variables on your meter:
• System contact: the name of the SNMP system administrator.
• System name: a descriptive name for your meter or the system where it is
installed.
• System location: a description of your meter’s location.

SNMP ports
The meter is configured to use standard SNMP ports to receive requests.

Port Description

161 Receives requests

When the SNMP agent (the meter) receives a request on port 161, a
response is sent to the source port on the NMS.

162 Receives notifications (traps)

The meter sends notifications from any available port.

SNMP trapping
SNMP trapping allows your meter’s agent to notify the NMS of events with an
unsolicited SNMP message (a “trap” of the meter’s alarm event).
SNMP trapping is only supported on SNMP v1.

Supported generic traps

SNMP generic traps supported by your meter are:
• coldStart: the meter (SNMP agent) is starting, and its configuration may have
been altered.
• warmStart: the meter (SNMP agent) is starting, and its configuration has not
been altered.
• linkDown: there is a failure in the communications link between the meter
(SNMP agent) and the NMS.
• linkUp: the SNMP agent is enabled and the communications link is
established.
• authenticationFailure: the meter (SNMP agent) has received an incorrect
community value.

Supported enterprise-specific traps

Your meter sends SNMP traps to the NMS for all high, medium and low priority
alarms configured on the meter. The trap includes information about the alarm,
such as the alarm label or description, timestamp, state, priority, value of the
parameter when the alarm occurred, and the alarm type.

Trap IP addresses
You can enter up to two IPv4 IP addresses for SNMP trap notification.

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Configuring SNMP using the webpages

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
You can configure your meter’s SNMP settings using the webpages.
1. Login to the meter webpages.
2. Based on your meter firmware version, click Settings > SNMP Settings OR
click Settings > Communication > SNMP Settings.
3. Modify the settings as required.

SNMP parameters available using the webpages

Parameter Values Description

Enable SNMP Yes / No Enables or disables SNMP on your meter

System Contact — Enter the name of your SNMP administrator

System Name — Enter a descriptive name for your meter

System Location — Enter your meter’s location

Read-only Community Name / Write- — Enter the community name used for SNMP requests
only Community Name
NOTE: It is highly recommended to set a community name that
best meets your security guidelines. The community Name
must contain between 8 and 16 characters with at least 1
uppercase, 1 lowercase and 1 special character.

Enable SNMP Traps Yes / No Enables SNMP trapping on your meter

Trap Receiver 1 IP Address / Trap — Enter up to 2 trap receiver IP addresses where trap messages are
Receiver 2 IP Address sent

FTP
Your meter has an internal FTP server that you can use to load files and upgrade
your meter and meter accessories.
FTP (File Transfer Protocol) is a standard, client-server network protocol used to
transfer files over Ethernet networks.
NOTE: To use FTP service for firmware versions mentioned in column (C) of
Table , the user must have accessed the meter webpage and set user account
credentials at least once. If this is already done, enable FTP (secured or
unsecured) through webpage or meter display or ION Setup. Subsequently
you can use valid Administrator user account credentials to access the FTP
server.

FTP file structure

Your meter’s FTP server contains fw and www / wwwroot folder.
• fw: this folder is where you can load firmware upgrade files for your meter and
the meter’s Ethernet card.
• www / wwwroot: this folder is where the meter’s default webpages are stored.
NOTE: The firmware upgrade process through FTP is only applicable for
meter models with firmware versions mentioned in column (A) and column (B)
of Table .

FTP file permissions

Based on your meter firmware version, you must use an user account assigned to
the Product Master group or Administrator role in order to access the meter’s
FTP server.

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FTP filename requirements

FTP filenames cannot include: spaces, “,” \, /, *, ?, <, >, and are limited to 68
characters in length, including the file extension.

Enabling and disabling the FTP server using the display

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
The Ethernet setup screen on the meter allows you to enable/disable FTP server.
1. Navigate to Maint > Setup.
2. Enter the setup passcode (default is “0”), then press OK.
3. Navigate to Comm > Enet.
4. Move the cursor to point to the parameter FTP you want to modify, then press
Edit.
5. Modify the parameter as required (Enabled/Disabled), then press OK.
6. Press the up arrow to exit.
7. Press Yes to save your changes.
NOTE:
The FTP can go to default state (Disabled):
• After 20 mins of being idle
• After every power-on
• After every firmware upgrade
In order to retain the FTP in Enabled state even after any of the above
conditions have occurred, upgrade your meter to the latest firmware
version:
• PM5560 / PM5562 / PM5563 / PM5580 meter models: 4.0.0 and
above
• PM5570 / PM5660 / PM5760 meter models: 6.0.0 and above
• PM5650 meter model: 4.10.0 and above
• PM5561 meter model: 12.0.0 and above
• PM5661 / PM5761 meter models: 14.0.0 and above

Enabling and disabling the FTP server using the webpages

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
The FTP server on the meter needs to be enabled for certain meter functionality.
NOTE: The FTP server is Disabled by default for security reasons. You can
Enable the FTP server, if required. It is recommended to use encrypted FTP
(FTPS).
1. Login to the meter webpages.
2. Based on your meter firmware version, click Settings > Advanced Ethernet
Settings OR click Settings > Communication > Advanced Ethernet
Settings.
3. Set FTP Server to Enabled or Disabled.
4. Click Save Changes or Apply Changes to save your changes to the meter.

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Time and timekeeping

Setting the clock using the display
The Clock setup screens allow you to set the meter’s date and time.
NOTE: You must always set or sync the meter time to UTC (GMT, Greenwich
Mean Time), not local time. Use the GMT Offset (h) setup parameter to
display the correct local time on the meter.
1. Navigate to Maint > Setup.
2. Enter the setup passcode (default is “0”), then press OK.
3. Navigate to Clock.
4. Move the cursor to point to the parameter you want to modify, then press
Edit.
5. Modify the parameter as required, then press OK.
6. Move the cursor to point to the next parameter you want to modify, press Edit,
make your changes, then press OK.
7. Press the up arrow to exit.
8. Press Yes to save your changes.

Parameter Values Description

Date DD/MM/YY Set the current date using the format displayed on screen, where DD = day, MM =
month and YY = year.
MM/DD/YY

YY/MM/DD
Time HH:MM:SS (24 hour Use the 24-hour format to set the current time in UTC (GMT).
format)

HH:MM:SS AM or PM
Meter Time GMT, Local Select GMT if you set the current time to Greenwich Mean Time zone. Otherwise,
select Local.
GMT Offset (h) 6 ± HH.0 Available only when Meter Time is set to Local. Set the GMT Offset between ±
00.0 and ± 12.0

To configure the clock using ION Setup, see the section for your meter in the
ION Setup online help or in the ION Setup device configuration guide,
available for download at www.se.com.

Setting the meter’s clock manually using the webpages

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
You can set the meter’s clock manually using the webpages.
NOTE: You can only set the time manually if Enable Network Time
Synchronization is set to No.
1. Login to the meter webpages.
2. Based on your meter firmware version, click Settings > Date/Time Settings
OR click Settings > Communication > Date Time Settings.
3. Use the dropdown lists to set the time and date you want to send to the meter.
NOTE: The default entry is the current date and time on the meter.

6. Currently supports whole integers only.

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4. Click Save changes or Apply Changes to save the time to your meter.

Configuring time and time synchronization using the webpages

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
You can configure time and time synchronization using the webpages.
1. Login to the meter webpages.
2. Based on your meter firmware version, click Settings > Date/Time Settings
OR click Settings > Communication > Date Time Settings.
3. Click Yes beside Enable Network Time Synchronization if you want to use
an SNTP server to synchronize the meter’s clock.
a. Set the Poll Interval to specify how often the meter synchronizes over
SNTP.
b. Enter the IP address for the Primary SNTP server and Secondary
SNTP server.
NOTE: Last Successful Time Synchronization displays the date and
time of the last synchronization over SNTP and the IP address of the
server that sent the signal.
4. Enter the meter’s clock settings and click Save changes or Apply Changes.

Parameter Values Description

Time Zone Offset UTC, UTC±H Select UTC to display the current time in UTC (Greenwich Mean
Time zone).

To display local time, set this parameter to the UTC offset for your
local time. For example, to display the local standard time in San
Fransisco on the meter, select UTC-8.
NOTE: You must either enable automatic daylight savings time
adjustment or manually update this setting to account for
daylight savings time.

Enable Automatic Daylight Yes, No Set this to Yes to automatically update the time to account for
Savings Time Adjustment daylight savings time, then enter the start and end date and time for
daylight savings time.

Daylight Savings Time Begins / — Select the start and end date and time for daylight savings time in
Daylight Savings Time Ends the meter’s location.

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Logging
Data log
The meter is shipped from the factory with data logging enabled for selected
values.
Typically, delivered energy (kWh, kVARh and kVAh) is logged by default, but you
can configure the meter to record other measurements, such as received energy,
input metering accumulations and peak demand values from previous demand
intervals.

Setting up the data log

You can select up to 14 items to record in the data log and the frequency (logging
interval) that you want those values updated.
Use ION Setup to configure data logging.

NOTICE
DATA LOSS
Save the contents of the data log before configuring it.
Failure to follow these instructions can result in data loss.

1. Start ION Setup and open your meter in setup screens mode (View > Setup
Screens). See the ION Setup Help for instructions.
2. Double-click Data Log #1.
3. Set up the logging frequency and measurements/data to log.
4. Click Send to save the changes to the meter.

Parameter Values Description

Status Enable, Disable Set this parameter to enable

or disable data logging in the
meter.
Interval 1 minute, 5 minutes, Select a time value to set the
10 minutes, 15 minutes, logging frequency.
30 minutes, 1 hour, 24 hours

Channels Items available for logging Select an item to record from

can vary based on the meter the “Available” column, then
type. click the double-right arrow
button to move the item to
the “Selected” column.

To remove an item, select it

from the “Selected” column
then click the double-left
arrow button.

Saving the data log contents using ION Setup

You can use ION Setup to save the contents of the data log.
1. Start ION Setup and open your meter in data screens mode (View > Data
Screens. See the ION Setup help for instructions.
2. Double-click Data Log #1 to retrieve the records.

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3. Once the records have finished uploading, right-click anywhere in the viewer
and select Export CSV from the popup menu to export the entire log.
NOTE: To export only selected records in the log, click the first record you
want to export, hold down the SHIFT key and click the last record you
want to export, then select Export CSV from the popup menu.
4. Navigate to the folder where you want to save the data log file, then click
Save.

Setting up device log exports using the webpages

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
You can set up the meter to export its logs to a web server, either on a schedule or
manually.
NOTE: Device log export times can vary, depending on the number of records
to export. To avoid long log export times, consider reducing the logging
frequency for the recorded items or selecting a more frequent log export
schedule (e.g., weekly instead of monthly).
1. Login to the meter webpages.
2. Based on your meter firmware version, click Settings > Device Log Export
OR click Settings > Communication > Device Log Export.
3. Click Yes to Enable HTTP Device Log Export.
4. Set the Frequency and configure the schedule as required.
– Daily: select Daily to set the meter data log export to once a day. Use the
Time of Day field to select what time the data log export occurs each day.
– Weekly: select Weekly to set the meter data log export to once a week.
Use the Time of Day and Day of the Week fields to select what time and
day the data log export occurs each week.
– Monthly: select Monthly to set the meter data log export to once a month.
Use the Time of Day and Day of the Month fields to select what time and
day the data log export occurs each month.
NOTE: You can leave the default settings if you are exporting the data
logs manually.
5. Configure the HTTP parameters as appropriate.
You can use the Test HTTP button to test the meter connection to the web
server.

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6. Click Save changes or Apply Changes to send and save the new settings to
the meter if you are configuring an export schedule, or click Manual Export to
export the data logs immediately.

Log export HTTP parameters available using the webpages

Parameter Description

Server IP Address 7 Enter the IP address of the server for the data log export.

Server TCP Port 7 Enter the server port number for HTTP communications.

Proxy Server IP Address 7 Enter the proxy server IP address, if required by your network.

Proxy Server TCP Port 7 Enter the proxy server TCP port number, if required by your network.

PATH Enter the network path of the folder where the data logs are to be exported.

Field Name Enter the name of the exported data log.

Host Name If using a virtual host name, enter the name here.

Username Enter the username for accessing the server.

Password Enter the password for accessing the server.

Alarm log
Alarm records are stored in the meter’s alarm history log.
You can use the meter’s display or a web browser to view the alarm history log.

Maintenance log
The meter records maintenance-type events such as changes to meter setup.
You can use a web browser to view the contents of the maintenance log.

7. Contact your local network administrator for parameter values.

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Inputs / outputs
I/O overview
The meter is equipped with digital I/O, RCM, and analog inputs.
The meter has:
• 4 digital inputs (S1 to S4)*
OR
2 digital inputs (S1 & S2) and 2 analog inputs (A1 & A2)*
OR
2 digital inputs (S1 & S2) and 2 RCM inputs (I5 & I6)*
• 2 Form A digital outputs (D1 & D2)
NOTE: *Available in specific meter models. Refer to Features
differentiation matrix for PM5500 / PM5600 / PM5700 series, page 20 for
the availability.

NOTICE
RISK OF DAMAGE TO THE METER
• Do not exceed the specified ratings.
• Refer to details in Device specifications section of this document.
Failure to follow these instructions can result in equipment damage.

Digital input applications

Digital inputs are typically used for monitoring the status of external contacts or
circuit breakers. They can also be used for pulse counting or input metering
applications, such as WAGES (water, air, gas, electricity, steam) monitoring.

Digital input wiring considerations

The meter’s digital inputs require an external voltage source to detect the digital
input’s on/off state.
The meter detects an on state, if the external voltage appearing at the digital input
is within its operating range.

WAGES monitoring
WAGES monitoring allows you to record and analyze all energy sources and
utilities usage.
Your system may use several different types of energy. For example, you may
consume steam or compressed air for industrial processes, electricity for lights
and computers, water for cooling and natural gas for heating. WAGES monitoring
collects the usage information from all these different energy sources to enable a
more complete energy analysis.
WAGES information can help you:
• Identify losses or inefficiencies.
• Modify demand to reduce costs.
• Optimize energy source usage.

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WAGES example
This example shows WAGES monitoring for a water flow meter.
You can connect your meter’s digital input to a transducer that sends a pulse for
every 15 kiloliters (4000 US Gal) of water. After configuring an input metering
channel and assigning it to the digital input, the meter is able to detect and record
the incoming pulses. An energy management system can then use the information
from the meter to perform WAGES analysis.

30

A. Water flow meter (15 kL/pulse)

B. Energy meter with digital input 1 assigned to input metering channel 1 and configured with unit
kL (kiloliters)
C. Energy management system with WAGES analysis capabilities

Configuring digital inputs using ION Setup

You can use ION Setup to configure the digital inputs.
1. Start ION Setup.
2. Connect to your meter.
3. Configure the control mode you want to use for the digital output.

Option Description

Normal
Input Metering 1. Navigate to I/O configuration > Input Metering.
2. Select the input metering channel you want to configure and
click Edit.
3. Configure the input metering channel parameters as required.
4. Select the digital input you want to associate with the input
metering channel and click the arrows to add it to the assigned
inputs.

Multi-Tariff 1. Navigate to Multi-Tariff.

2. Proceed through the Multi-Tariff configuration wizard, setting the
control mode to Input and selecting the digital input(s) you want
to associate.
Demand Sync 1. Navigate to Demand Setup.
2. Select the demand type that you want to associate with the
digital input and click Edit.
3. Configure the demand mode parameters as required, setting the
mode to one of the input options.
4. Click the Digital Input Association button to associate a digital
input.

4. Navigate to I/O configuration > I/O Setup.

5. Select a digital input to configure and click Edit.
The setup screen for that digital input is displayed.
6. Configure the setup parameters as required.

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7. Click Send to save your changes.

Digital input setup parameters

Parameter Values Description

Label — Use this field to change the default label and assign a descriptive name to this
digital input.

Control Mode Normal This field displays how the digital input functions.
• Normal: the digital input is either associated with a digital input alarm, or it is
Demand Sync not associated with another meter function. The meter counts and records
the number of incoming pulses normally.
Input Metering
• Demand Sync: the digital input is associated with one of the input sync
Multi-Tariff demand functions. The meter uses the incoming pulse to synchronize its
demand period with the external source.
• Input Metering: the digital input is associated with one of the input metering
channels. The meter counts and records the number of incoming pulses and
related consumption data associated with the pulses.
• Multi-Tariff: the digital input is associated with the multi-tariff function.
NOTE: The control mode is set in the ION Setup where you configure the
feature.
Debounce 0 to 1000 Debounce is the time delay that compensates for mechanical contact bounce.
Use this field to set how long (in milliseconds) the external signal must remain in a
certain state to be considered a valid state change. Allowable values are
increments of 10 (i.e., 10, 20, 30, etc., up to 1000 ms).

Associations — This field displays additional information if the digital input is already associated
with another meter function.

Configuring digital inputs using the display

You can use the display to configure the digital inputs.
NOTE: It is recommended you use ION Setup to configure the digital inputs,
as setup parameters that require text entry can only be modified using ION
Setup.
1. Navigate to Maint > Setup.
2. Enter the setup passcode (default is “0”), then press OK.
3. Navigate to I/O > D In.
4. Move the cursor to point to the digital input you want to set up, then press
Edit.
5. Move the cursor to point to the parameter you want to modify, then press
Edit.
NOTE: If Edit is not displayed, it means the parameter is either read-only
or can only be modified through software.
6. Modify the parameter as required, then press OK.
7. Move the cursor to point to the next parameter you want to modify, press Edit,
make your changes, then press OK.

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8. Press the up arrow to exit. Press Yes to save your changes.

Digital input setup parameters available using the display

Parameter Values Description

Label — This can be modified only through software. Use this field to assign names to the
digital inputs.

Debounce Time (ms) 0 to 1000 Debounce is the time delay that compensates for mechanical contact bounce.
Use this field to set how long (in milliseconds) the external signal must remain in a
certain state to be considered a valid state change. Allowable values are
increments of 10 (i.e., 10, 20, 30, etc., up to 1000 ms).

Control Mode Normal This field displays how the digital input functions.
• Normal: the digital input is either associated with a digital input alarm, or it is
Demand Sync not associated with another meter function. The meter counts and records
the number of incoming pulses normally.
Input Metering
• Demand Sync: the digital input is associated with one of the input sync
Multi-Tariff demand functions. The meter uses the incoming pulse to synchronize its
demand period with the external source.
• Input Metering: the digital input is associated with one of the input metering
channels. The meter counts and records the number of incoming pulses and
related consumption data associated with the pulses.
• Multi-Tariff: the digital input is associated with the multi-tariff function.

Input metering
Your meter’s digital inputs can be used to count pulses from transducers and
convert the pulses to energy measurements.
Your meter’s input metering channels count pulses received from the digital inputs
assigned to that channel. The incoming pulses are used in calculating and
measuring consumption data (e.g., BTU, kWh, L, kg). Each channel must have the
following values configured to match the pulse data:
• Pulse Weight: the pulses per unit value.
• Unit Code: the unit of measure associated with the monitored value.
• Demand Code: for time-based values (such as kWh), this provides the
associated demand units (kW) for demand calculations; for other values
(such as kg), this can be configured to provide rate information (kg/h or kg/s).
• Mode: whether a pulse is based on a complete pulse or a transition.

For example, if each complete pulse represents 125 Wh, you can configure for Wh
pulsing as follows:
• Pulse Weight = pulses/Wh = 1/125 = 0.008
• Unit Code = Wh
• Demand Code = kW (this is automatically set)
• Mode = pulse
If you want to configure for kWh pulsing, you must adjust the pulse weight
calculation and unit code as follows:
• Pulse Weight = pulses/kWh = 1/0.125 = 8
• Unit Code = kWh

Configuring input metering using ION Setup

You can use ION Setup to configure the input metering channels.
1. Start ION Setup.
2. Connect to your meter.
3. Navigate to I/O configuration > Input metering

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4. Select an input metering channel to configure and click Edit.

The Channel Setup screen is displayed.
5. Enter a descriptive name for the metering channel’s Label.
6. Configure the input metering parameters as required.
7. Click Send to save your changes.

Parameter Values Description

Label — Use this field to change the default label and assign a descriptive
name to this input metering channel.

Pulse Weight 0 to 99.99999 Use this field to specify the quantity or value each pulse represents.

Units No units, Wh, kWh, MWh, Select the unit of measurement associated with the monitored
VARh, kVARh, MVARh, VAh, value.
kVAh, MVAh, gal, BTU, L, m3,
MCF, lbs, kg, klbs, Therm

Rate Varies (based on the units For time-based values (such as kWh), this provides the associated
selected) demand units (kW) for demand calculations. For other values (such
as kg), this can be configured to provide rate information (kg/h).

Mode Pulse or Transition Set Mode to Pulse to count only complete pulses. Set Mode to
Transition to count each ON-to-OFF or OFF-to-ON status change.

Available Inputs / Assigned Digital input DI1, DI2, DI3*, DI4* Select the digital input from the Available inputs box and use the
Inputs right arrow button to assign the input metering channel to that digital
input.

*Available in specific meter models. Refer to Features differentiation matrix for PM5500 / PM5600 / PM5700 series, page 20 for the
availability.

Configuring input metering using the display

You can use the meter’s display to configure the input metering channels.
NOTE: It is recommended you use ION Setup to configure input metering, as
setup parameters that require text entry can only be modified using ION
Setup.
1. Navigate to Maint > Setup.
2. Enter the setup passcode (default is “0”), then press OK.
3. Navigate to I/O > Inp Mtr.
4. Move the cursor to point to the input metering channel you want to set up,
then press Edit.
5. Move the cursor to the parameter you want to modify, then press Edit.
NOTE: If Edit is not displayed, it means the parameter is either read-only
or can only be modified through software.
6. Modify the parameter as required, then press OK.

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7. Press the up arrow to exit. Press Yes to save your changes.

Parameter Values Description

Label — Use this field to change the default label and assign a descriptive
name to this input metering channel.

Pulse Weight 0 to 99.99999 Use this field to specify the quantity or value each pulse represents.

Unit Code None, Wh, kWh, MWh, VARh, Select the unit of measurement associated with the monitored
kVARh, MVARh, VAh, kVAh, value.
MVAh, gal, BTU, L, m3, MCF,
lbs, kg, klbs, Therm

Demand Code Varies (based on the units For time-based values (such as kWh), this provides the associated
selected) demand units (kW) for demand calculations. For other values (such
as kg), this can be configured to provide rate information (kg/h).

Mode Pulse, Transition Set Mode to Pulse to count only complete pulses. Set Mode to
Transition to count each ON-to-OFF or OFF-to-ON status change.

Digital Inputs None, Digital input Select the digital input from the Available inputs box and use the
right arrow button to assign the input metering channel to that digital
input.

Demand measurements for input metering

The demand codes available for input metering are based on the unit code
selected when you configure input metering on your meter.

Input metering unit and demand codes

Unit Code Demand Code Description

None None Default setting for the input metering channels

Wh kW Watt-hour, kiloWatt-hour and MegaWatt-hour

measurements are converted to calculate demand in kW
kWh .
MWh
VARh kVAR VAR-hour, kiloVAR-hour and MegaVAR-hour
measurements are converted to calculate demand in
kVARh kVAR.
MVARh
VAh kVA VA-hour, kiloVA-hour and MegaVA-hour measurements
are converted to calculate demand in kVA.
kVAh
MVAh
gal GPH, GPM Select GPH to set rate to gallons per hour or GPM to set it
to gallons per minute.

BTU BTU/h BTU (British thermal unit) energy measurements are set to
calculate BTUs per hour consumption rate.

L l/hr, l/min Select liters per hour or per minute consumption rate.

m3 m3/hr, m3/s, m3/m Select cubic meters per hour, per second, or per minute
consumption rate.

MCF cfm Thousand cubic foot volume measurments are converted

to calculate cubic feet per minute consumption rate.

lbs lb/hr Kilopounds (klbs) measurements are converted to

calculate pounds per hour consumption rate.
klbs
kg kg/hr Kilogram measurements are set to calculate kilogram per
hour consumption rate.

Therm Thm/h British therm (equivalent to 100,000 BTU) heat

measurements are set to calculate therm per hour
consumption rate.

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Viewing input metering data through the meter’s display

You can use the meter’s display to view input metering data.
1. Navigate to Energy > Inp Mtr > Dmd.
2. Select an input metering channel to view the input metering data.
NOTE: The display shows accumulation values from 0 to 99999. The
display rolls over to zero when the accumulated value reaches 100,000
and starts incrementing again.

Digital output applications

Digital outputs are typically used in switching applications, for example, to provide
on/off control signals for switching capacitor banks, generators, and other external
devices and equipment.
The digital output can also be used in demand synchronization applications,
where the meter provides pulse signals to the input of another meter to control its
demand period. The digital output can also be used in energy pulsing applications,
where a receiving device determines energy usage by counting the kWh pulses
coming from the meter’s digital output.
The digital outputs on the meter are internally designed using solid-state devices
with an open-collector configuration. These outputs must be connected to the
specified power supply with a current limiter to function. Refer to the digital output
application example below for more information.

Digital output application example

You can connect one of your meter’s digital outputs to a relay that switches on a
generator and the other digital output to send a demand sync pulse to other
meters.
In the following example, the first meter (Meter 1) controls and sets the demand
period (900 seconds) of the other meters (Meter 2, Meter 3, Meter 4) through the
output pulse occurring at the end of the first meter’s demand interval.

A Relay
Meter 1
B Demand period (in this example,
D1 D2 900 seconds)
+ - + -

Power +
source
125 mA
40 V AC /
60 V DC -

Meter 2 Meter 3 Meter 4

Configuring digital outputs using ION Setup

You can use ION Setup to configure the digital outputs (D1 and D2).
1. Start ION Setup.
2. Connect to your meter.

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3. Configure the control mode you want to use for the digital output.

Option Description

External or Energy Pulsing 1. Navigate to I/O configuration > Energy Pulsing.

2. Select the digital output you are configuring and click Edit.
3. Select External or Energy from the Control dropdown list.
4. For Energy, configure the energy pulsing parameters as required.

Alarm 1. Navigate to Alarming.

2. Select the alarm type of the alarm you want to associate with the digital output and click Edit.
3. Configure the alarm parameters as required.
4. Select the digital output you want to associate with the alarm.
NOTE: You may need to enable the alarm before you can associate the digital output.

Demand 1. Navigate to Demand Setup.

2. Select the demand type that you want to associate with the digital output and click Edit.
3. Configure the demand mode parameters as required.
4. Click the Digital Output Association button to associate a digital output.

4. Navigate to I/O configuration > I/O Setup.

5. Select a digital output to configure and click Edit.
The setup screen for that digital output is displayed.
6. Enter a descriptive name for the digital output in the Label field.
7. Configure the Behavior Mode and On Time parameters as required,
depending on the control mode.
8. Click Send to save your changes.

Digital output setup parameters available using ION Setup

Parameter Values Description

Label — Use this field to change the default label and assign a descriptive name to this digital output.

Control Mode External, Demand, This field displays how the digital output functions.
Alarm, Energy
• External: the digital output is controlled remotely either through software or by a PLC
using commands sent through communications.
• Demand: the digital output is associated with one of the demand systems. The meter
sends a pulse to the digital output at the end of every demand interval.
• Alarm: the digital output is associated with the alarm system. The meter sends a pulse to
the digital output when the alarm is triggered.
• Energy: the digital output is associated with energy pulsing. When this mode is selected,
you can select the energy parameter and the set the pulse rate (pulses/kW).
NOTE: The control mode is set in the ION Setup where you configure the feature.

Behavior Mode Normal, Timed, Coil • Normal: this mode applies when control mode is set to External or Alarm. The digital
Hold output remains in the ON state until an OFF command is sent by the computer or PLC.
• Timed: the digital output remains ON for the period defined by the On Time setup register.
• Coil Hold: this mode applies when control mode is set to External or Alarm. For a unary
alarm that is associated with a digital output, you must set Behavior Mode to Coil Hold.
The output turns on when the “energize” command is received and turns off when the “coil
hold release” command is received. In the event of a control power loss, the output
remembers and returns to the state it was in when control power was lost.

On Time (s) 0 to 9999 This setting defines the pulse width (ON time) in seconds.

Associations — This field displays additional information if the digital output is already associated with another
meter function.

Configuring digital outputs using the display

You can use the display to configure the digital outputs.
NOTE: It is recommended you use ION Setup to configure the digital outputs,
as setup parameters that require text entry can only be modified using
software.

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1. Navigate to Maint > Setup.

2. Enter the setup passcode, then press OK.
3. Navigate to I/O > D Out.
4. Move the cursor to point to the digital output you want to set up, then press
Edit.
5. Edit the parameters as required.
a. Move the cursor to point to the parameter you want to modify, then press
Edit
b. Modify the parameter as required, then press OK.
c. Move the cursor to point to the next parameter you want to modify, press
Edit, make your changes, then press OK.
NOTE: If Edit is not displayed, it means the parameter is either read-only
or can only be modified through software.
6. Press the up arrow to exit. Press Yes to save your changes.

Setting Option or range Description

Label — This can be modified only through software. Use this field to change the default label
and assign a descriptive name to this digital output.

Control Mode External, Demand Sync, This field displays how the digital output functions.
Alarm, Energy • External: the digital output is controlled remotely either through software or by a
PLC using commands sent through communications.
• Demand Sync: the digital output is associated with one of the demand systems.
The meter sends a pulse to the digital output at the end of every demand
interval.
• Alarm: the digital output is associated with the alarm system. The meter sends a
pulse to the digital output when the alarm is triggered.
• Energy: the digital output is associated with energy pulsing. When this mode is
selected, you can select the energy parameter and the set the pulse rate
(pulses/kW).

Behavior Mode Normal, Timed, Coil Hold • Normal: this mode applies when control mode is set to External or Alarm. The
digital output remains in the ON state until an OFF command is sent by the
computer or PLC.
• Timed: the digital output remains ON for the period defined by the On Time
setup register.
• Coil Hold: this mode applies when control mode is set to External or Alarm. For a
unary alarm that is associated with a digital output, you must set Behavior Mode
to Coil Hold. The output turns on when the “energize” command is received and
turns off when the “coil hold release” command is received. In the event of a
control power loss, the output remembers and returns to the state it was in when
control power was lost.

On Time (s) 0 to 9999 This setting defines the pulse width (ON time) in seconds.

Select Dmd System Power, Current, Input Applies when Control Mode is set to Demand Sync. Select the demand system to
Metering monitor.

Select Alarms All available alarms Applies when Control Mode is set to Alarm. Select one or more alarms to monitor.

Energy pulsing
You can configure the meter’s energy pulsing LED or digital output for energy
pulsing applications.
When the LED is set to energy pulsing, the meter sends a readable pulse or signal
based on the measured energy. This pulse can be used for accuracy verification
or as an input to another energy monitoring system. You must calculate your pulse
values as either pulses per kWh or as kWh per pulse, as defined by your meter,
and set the energy value as delivered or received active, reactive, or apparent
energy.

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Configuring the alarm / energy pulsing LED using the display

You can use the display to configure your meter’s LED for alarming or energy
pulsing applications.
NOTE: The alarm / energy pulsing LED on the PM5561 / PM5661 / PM5761 is
permanently set for energy pulsing.
1. Navigate to Maint > Setup.
2. Enter the setup passcode (default is “0”), then press OK.
3. Navigate to I/O > LED.
4. Move the cursor to point to the parameter you want to modify, then press
Edit.
5. Press the plus or minus buttons to modify the parameter as required, then
press OK.
6. Press the up arrow to exit. Press Yes to save your changes.

Setting Option or range Description

Mode Off, Alarm, Energy Off disables the LED completely.

Alarm sets the LED for alarm notification.

Energy sets the LED for energy pulsing.

Pulses per k__h 1 to 9999999 When configured for energy pulsing, this setting defines how
many pulses are sent to the LED for every 1 kWh, 1 kVARh
or 1kVAh accumulated energy. This setting is ignored when
the LED mode is set to Alarm.
Channel Active Del, Select which accumulated energy channel to monitor and
use for energy pulsing. This setting is ignored when the LED
Active Rec, mode is set to Alarm.
Active Del + Rec,

Reactive Del,

Reactive Rec,

Reactive Del + Rec,

Apparent Del,

Apparent Rec,

Apparent Del + Rec

Configuring the alarm / energy pulsing LED or digital output for energy pulsing using
ION Setup
You can use ION Setup to configure your meter’s alarm / energy pulsing LED or
digital output for energy pulsing.
NOTE: The alarm / energy pulsing LED on the PM5561 / PM5661 / PM5761 is
permanently set for energy pulsing and cannot be disabled or used for alarms.
1. Start ION Setup.
2. Connect to your meter.
3. Navigate to I/O configuration > Energy Pulsing.
4. Select the LED or a digital output to configure and click Edit.
The setup screen is displayed.
5. Enter a descriptive name for the digital output’s Label.
6. Configure the other setup parameters as required.

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7. Click Send to save your changes.

Alarm / energy pulsing setup parameters available using ION Setup

Parameter Values Description

Mode LED: Disabled, Alarm, LED:

Energy • LED is disabled.
Digital output: External, • Alarm sets the LED for alarm notification.
Energy • Energy sets the LED for energy pulsing.
Digital output:
• Energy: associates the digital output with energy pulsing.
• External: disassociates the digital output from energy pulsing.

Pulse rate 1 to 9999999 When configured for energy pulsing, this defines how many pulses are sent to the LED
(pulses/kW) for every 1 kWh, 1 kVARh or 1kVAh of accumulated energy.

Parameter Active Energy Delivered Select which accumulated energy channel to monitor and use for energy pulsing.

Active Energy Received

Active Energy Del+Rec

Reactive Energy Delivered

Reactive Energy Received

Reactive Energy Del+Rec

Apparent Energy Delivered

Apparent Energy Received

Apparent Energy Del+Rec

Analog inputs
Applicable only in PM5570 meter model.
The analog inputs are typically used to measure flow rates, temperatures,
pressures, rotations, and fluid levels through electrical signals from transducers.
For analog input operation, your meter processes an analog input signal and
provides the resulting scaled value. Your meter’s analog inputs can measure
current using standard 4 - 20 mA analog transducers.
You need to configure analog inputs’s minimum and maximum values. Analog
inputs may show a value below zero scale if an open circuit is detected on the
input.

Configuring analog inputs using the display

You can use the display to configure the analog inputs.
NOTE: It is recommended you use ION Setup to configure Label details
(Analog Input 1 / Analog Input 2), as setup parameters that require text entry
can only be modified using ION Setup.
1. Navigate to Maint > Setup.
2. Enter the setup passcode (default is “0”), then press OK.
3. Navigate to I/O > A In and press A In.
4. Move the cursor to point to Analog Input 1 / Analog Input 2 you want to
modify, then press Edit.
NOTE: If Edit is not displayed, it means the parameter is either read-only
or can only be modified through software.
5. Modify the parameters as required, then press OK.

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6. Press the up arrow to exit. Press Yes to save your changes.

Analog input setup parameters available using the display

Parameter Values Description

Label – This can be modified only through ION Setup. Use this field to assign names to
the analog inputs.

Scale 0.001 (Default) Select the scaling value from the list.

10

100

1000

0.010

0.100
Unit Refer to Configurable Select the unit of measurement associated with the monitored value.
units, page 138 table

Minimum Value -999999 The minimum source value that matches the minimum analog input signal.

Maximum Value +999999 The maximum source value that matches the maximum analog input signal.

NOTE: The meter LCD displays a maximum of 5 digits for the Scaled
Value of Analog Inputs A1 and A2. If the Minimum Value, Maximum
Value, and Scale settings result in a Scaled Value longer than 5 digits,
the Scaled Value on the LCD may appear clipped or blank. It is advised
to check the sensor's range and units during selection.

Configurable units

Code Unit Description

0 – No unit
1 % Percentage

2 ºC Degrees Celsius

3 ºF Degrees Fahrenheit

4 Deg Degrees Angular

5 Hz Hertz
6 A Amperes
(Default)

7 kA Kilo Amperes

8 V Volts
9 kV Kilo Volts
10 MV Mega Volts

11 W Watts
12 kW Kilowatts
13 MW Megawatts

14 VAR Volt-Ampere Reactive

15 kVAR Kilo Volt-Ampere Reactive

16 MVAR Mega Volt-Ampere Reactive

17 VA Volt-Amperes

18 kVA Kilo Volt-Amperes

19 MVA Mega Volt-Amperes

20 WH Watt-Hour

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Code Unit Description

21 kWH Kilowatt-Hour
22 MWH Megawatt-Hour

23 VARH Reactive Volt-Ampere Hour

24 kVARH Reactive Kilo Volt-Ampere Hour

25 MVARH Reactive Mega Volt-Ampere Hour

26 VAH Volt-Ampere Hours

27 kVAH Kilo Volt-Ampere Hours

28 MVAH Mega Volt-Ampere Hours

29 Seconds Seconds
30 Minutes Minutes
31 Hours Hours
32 Bytes (RAM) Bytes

33 kBytes (RAM) Kilobytes

34 $ Dollars

35 gal Gallons

36 gal/hr Gallons/hour

37 gal/min Gallons/minute

38 cfm Cubic feet/min

39 PSI PSI
40 BTU BTU
41 L Liters
42 ton-hours Ton-hours
43 l/hr Liters/hour
44 l/min Liters/min
45 € Euros
46 ms Milliseconds
47 m3 Cubic-meters
48 m3/sec Cubic-meters/sec
49 m3/min Cubic-meters/min
50 m3/hr Cubic-meters/hour
51 Pa Pascals
52 Bars Bar
53 RPM Revolutions/min
55 BTU/hr BTU/hour
56 PSIG Pounds/square inch gauge

57 SCFM Standard cubic feet/min

58 MCF Thousand cubic feet
59 Therm Therm
60 SCFH Standard cubic feet/hour
61 PSIA Pounds/square inch absolute

62 lbs Pounds
63 kg Kilogram

64 klbs Kilopounds

65 lb/hr Pound/hour
66 ton/hr Ton/hour

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Code Unit Description

67 kg/hr Kilogram/hour

68 in. Hg Inch of Mercury

69 kPa KiloPascals
70 %RH Percentage of relative humidity

71 MPH Miles per hour

72 m/sec Meters/sec
73 mV/cal/(cm²/min) MilliVolts/calorie/(square centimeters/min)

74 in Inches
75 mm Millimeter
76 GWH GigaWatt-Hour

77 GVARH Reactive Giga Volt-Ampere Hour

78 GVAH Giga Volt-Ampere Hours

79 AH Ampere-Hours

80 kAH Kiloamp-Hours

81 Therm/hr Therm/hour

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Resets
Meter resets
Resets allow you to clear various accumulated parameters stored on your meter
or reinitialize the meter or meter accessories.
Meter resets clear your meter’s onboard data logs and other related information.
Resets are typically performed after you make changes to the meter’s basic setup
parameters (such as frequency, VT/PT or CT settings) to clear invalid or obsolete
data in preparation for putting the meter into active service.

Meter Initialization
Meter Initialization is a special command that clears the meter’s logged data,
counters and timers.
It is common practice to initialize the meter after its configuration is completed,
before adding it to an energy management system.
After configuring all the meter setup parameters, navigate through the different
meter display screens and make sure the displayed data is valid then perform
meter initialization.

Performing global resets using the display

Global resets allow you to clear all data of a particular type, such as all energy
values or all minimum/maximum values.
1. Navigate to Maint > Resets.
2. Move the cursor to point to Global Resets, then press Select.
3. Move the cursor to point to the parameter you want to reset, then press
Reset.

Option Description

Meter Initialization Clears all data listed in this table (energy, demand, min/max values, counters, logs, timers and
input metering data).

Energies Clears all accumulated energy values (kWh, kVARh, kVAh).

Demands Clears all the demand registers.

Min/Max Clears all the minimum and maximum registers.

Alarm Counts & Logs Clears all the alarm counters and alarm logs.

I/O Counts & Timers Clears all the I/O counters and resets all the timers.
Input Metering Clears all input metering energy data.

4. Enter the reset passcode (default is “0”), then press OK.

5. Press Yes to confirm the reset or No to cancel and return to the previous
screen.
To perform resets using ION Setup, see the “PM5500 / PM5600 / PM5700”
topic in the ION Setup online help or in the ION Setup device configuration
guide, available from www.se.com.

Performing single resets using the display

Single resets allow you clear data only in a specific register or register type.

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Single resets are often combined to allow you to clear all data of a similar type, for
example, a kWh, kVAR and kVA reset may be combined into an energy reset that
clears all of the meter’s energy logs.
1. Navigate to Maint > Resets.
2. Move the cursor to point to Single Resets, then press Select.
3. Move the cursor to point to the parameter you want to reset, then press
Reset.
If there are additional options for the parameter, press Select, move the
cursor to point to the option you want, then press Reset.
4. Enter the reset passcode (default is “0”), then press OK.
5. Press Yes to confirm the reset or No to cancel and return to the previous
screen.
Available single resets using the display

Parameter Option Description

Energy Accumulated Clears all accumulated energy values (kWh, kVARh, kVAh).

Demand Power, Current, Input Metering Select which demand registers to clear (power demand, current demand or
input metering demand).

Alarms Event Queue Clears the alarm event queue register (active alarms list).

History Log Clears the alarm history log.

Counters Select Counters and then select which alarm counter to clear. See the
Alarm counter reset options table.

Digital Inputs Timers Select Timers then select which digital input timer to clear (chose all or
individual digital input timers): All Dig In Timers, Digital Input DI1, Digital
Input DI2, Digital Input DI3*, Digital Input DI4*

Counters Select Counters then select which digital input counter to clear (chose all
or individual digital input timers): All Dig In Counters, Digital Input DI1,
Digital Input DI2, Digital Input DI3*, Digital Input DI4*

Digital Outputs Timers Select Timers then select which digital output timer to clear (chose all or
individual digital input timers): All Dig Out Timers, Digital Output DO1,
Digital Output DO2

Counters Select Counters then select which digital output counter to clear (chose all
or individual digital input timers): All Dig Out Counters, Digital Output DO1,
Digital Output DO2

Active Load Timer — Clears and restarts the load operation timer.

Multi-Tariff — Clears accumulated values in all tariff registers.

Input Metering Reset All InptMtr Select which input metering channel (InpMtr Chan) to clear (chose all or
individual input metering channels).
Reset InpMtr Chan 1

Reset InpMtr Chan 2

Reset InpMtr Chan 3

Reset InpMtr Chan 4

*Available in specific meter models. Refer to Features differentiation matrix for PM5500 / PM5600 / PM5700 series, page 20 for the
availability.

To perform resets using ION Setup, see the “PM5500 / PM5600 / PM5700”
topic in the ION Setup online help or in the ION Setup device configuration
guide, available from www.se.com.

Performing user account resets using the display

If the Username or Password credentials for Administrator role account or for
multiple Administrator role accounts are lost, you can reset user accounts and
roles using the meter display.

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NOTE: For PM5563 meter model without PM5RD remote display, you must
buy PM5RD to perform this user account reset.
1. Navigate to Maint > Resets.
2. Move the cursor to point to User Acc Resets, then press Select.
3. Press Reset.
4. Enter the reset passcode (default is “0”), then press OK to reset the user
accounts and roles to factory default settings.
5. Press Yes to confirm the reset or No to cancel and return to the previous
screen.

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Alarms
Alarms overview
An alarm is the meter’s means of notifying you when an alarm condition is
detected, such as an error or an event that falls outside of normal operating
conditions. Alarms are typically setpoint-driven and can be programmed to
monitor certain behaviors, events or unwanted conditions in your electrical
system.
You can configure your meter to generate and display high, medium and low
priority alarms when predefined events are detected in the meter’s measured
values or operating states. Your meter also logs the alarm event information.
The meter ships with some alarms already enabled from the factory. Other alarms
need to be configured before the meter can generate alarms.
Customize meter alarms as required, such as changing the priority. You can also
create custom alarms using the advanced features of your meter.

Alarm types
Your meters supports a number of different alarm types.

Type Number

Unary 4

Digital 4 or 2*

Standard 29 or 33*
Logic 10

Custom 5
Disturbance 2*
(Sag/swell)

*Available in specific meter models. Refer to Features differentiation matrix for PM5500 / PM5600 /
PM5700 series, page 20 for the availability.

Unary alarms
A unary alarm is the simplest type of alarm — it monitors a single behavior, event
or condition.

Available unary alarms

Your meter has a set of 4 unary alarms.

Alarm label Description

Meter Powerup Meter powers on after losing control power.

Meter Reset Meter resets for any reason.

Meter Diagnostic Meter’s self-diagnostic feature detects a problem.

Phase Reversal Meter detects a phase rotation different than expected.

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Digital alarms
Digital alarms monitor the ON or OFF state of the meter’s digital / status inputs.

Digital alarm with setpoint delay

To prevent false triggers from erratic signals, you can set up pickup and dropout
time delays for the digital alarm.

1
∆T1 ∆T2
0
∆T3

EV1 EV2

A Pickup setpoint (1 = ON) ΔT2 Dropout time delay (in seconds)

B Dropout setpoint (0 = OFF) EV2 End of alarm condition

ΔT1 Pickup time delay (in seconds) ΔT3 Alarm duration (in seconds)

EV1 Start of alarm condition

NOTE: To prevent filling the alarm log with nuisance alarm trips, the digital
alarm is automatically disabled if the digital / status input changes state more
than 4 times in one second or more than 10 times in ten seconds. In this case,
you must re-enable the alarm using the display or ION Setup.

Available digital alarms

Your meter has a set of 4 or 2 digital alarms.

Alarm label Description

Digital Alarm S1 Digital input 1

Digital Alarm S2 Digital input 2

Digital Alarm S3 Digital input 3*

Digital Alarm S4 Digital input 4*

*Available in specific meter models. Refer to Features differentiation matrix for PM5500 / PM5600 /
PM5700 series, page 20 for the availability.

Standard alarms
Standard alarms are setpoint-driven alarms which monitor certain behaviors,
events or unwanted conditions in your electrical system.
Standard alarms have a detection rate equal to the 50/60 meter cycle, which is
nominally 1 second if the meter’s frequency setting is configured to match the
system frequency (50 or 60 Hz).
Many of the standard alarms are three-phase alarms. Alarm setpoints are
evaluated for each of the three phases individually, but the alarm is reported as a
single alarm. The alarm pickup occurs when the first phase exceeds the alarm
pickup magnitude for the pickup time delay. The alarm is active as long as any
phase remains in an alarm state. The alarm dropout occurs when the last phase
drops below the dropout magnitude for the dropout time delay.

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Example of over and under setpoint (standard) alarm operation

The meter supports over and under setpoint conditions on standard alarms.
A setpoint condition occurs when the magnitude of the signal being monitored
crosses the limit specified by the pickup setpoint setting and stays within that limit
for a minimum time period specified by the pickup time delay setting.
The setpoint condition ends when the magnitude of the signal being monitored
crosses the limit specified by dropout setpoint setting and stays within that limit for
a minimum time period specified by dropout time delay setting.

Over setpoint
When the value rises above the pickup setpoint setting and remains there long
enough to satisfy the pickup time delay period (ΔT1), the alarm condition is set to
ON. When the value falls below the dropout setpoint setting and remains there
long enough to satisfy the dropout time delay period (ΔT2), the alarm condition is
set to OFF.

A Pickup setpoint

B Dropout setpoint
Max2
Max1 ΔT1 Pickup time delay period (in seconds)

EV1 Start of alarm condition

∆T1
∆T2 ΔT2 Dropout time delay (in seconds)

∆T3
EV2 End of alarm condition
ΔT3 Alarm duration (in seconds)
EV1 EV2
Max1 Maximum value recorded during pickup period

Max2 Maximum value recorded during alarm period

The meter records the date and time when the alarm event starts (EV1) and when
it ends (EV2). The meter also performs any task assigned to the event, such as
operating a digital output. The meter also records maximum values (Max1, Max2)
before, during or after the alarm period.

Under setpoint
When the value falls below the pickup setpoint setting and remains there long
enough to satisfy the pickup time delay period (ΔT1), the alarm condition is set to
ON. When the value rises above the dropout setpoint setting and remains there
long enough to satisfy the dropout time delay period (ΔT2), the alarm condition is
set to OFF.

A Pickup setpoint
∆T3 B Dropout setpoint

ΔT1 Pickup time delay period (in seconds)

∆T2
EV1 Start of alarm condition
∆T1
ΔT2 Dropout time delay (in seconds)
Min1 EV2 End of alarm condition
Min2
ΔT3 Alarm duration (in seconds)
EV1 EV2
Min1 Minimum value recorded during pickup period

Min2 Minimum value recorded during alarm period

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The meter records the date and time when the alarm event starts (EV1) and when
it ends (EV2). The meter also performs any task assigned to the event, such as
operating a digital output. The meter also records minimum values (Min1, Min2)
before, during or after the alarm period.

Maximum allowable setpoint

The meter is programmed to help prevent user data entry errors, with set limits for
the standard alarms.
The maximum setpoint value you can enter for some of the standard alarms
depends on the voltage transformer ratio (VT ratio), current transformer ratio (CT
ratio), system type (i.e., number of phases) and/or the maximum voltage and
maximum current limits programmed at the factory.
NOTE: VT ratio is the VT primary divided by the VT secondary and CT ratio is
the CT primary divided by the CT secondary.

Standard alarm Maximum setpoint value

Over Phase Current (maximum current) x (CT ratio)

Under Phase Current (maximum current) x (CT ratio)

Over Neutral Current (maximum current) x (CT ratio) x (number of phases)

Over Ground Current (maximum current) x (CT ratio)

Over Voltage L-L (maximum voltage) x (VT ratio)

Under Voltage L-L (maximum voltage) x (VT ratio)

Over Voltage L-N (maximum voltage) x (VT ratio)

Under Voltage L-N (maximum voltage) x (VT ratio)

Over Active Power (maximum voltage) x (maximum current) x (number of phases)

Over Reactive Power (maximum voltage) x (maximum current) x (number of phases)

Over Apparent Power (maximum voltage) x (maximum current) x (number of phases)

Over Present Active Power Demand (maximum voltage) x (maximum current) x (number of phases)

Over Last Active Power Demand (maximum voltage) x (maximum current) x (number of phases)

Over Predicted Active Power Demand (maximum voltage) x (maximum current) x (number of phases)

Over Present Reactive Power Demand (maximum voltage) x (maximum current) x (number of phases)

Over Last Reactive Power Demand (maximum voltage) x (maximum current) x (number of phases)

Over Predicted Reactive Power Demand (maximum voltage) x (maximum current) x (number of phases)

Over Present Apparent Power Demand (maximum voltage) x (maximum current) x (number of phases)

Over Last Apparent Power Demand (maximum voltage) x (maximum current) x (number of phases)

Over Predicted Apparent Power Demand (maximum voltage) x (maximum current) x (number of phases)

Over Voltage Unbalance (maximum voltage) x (VT ratio)

Phase Loss (maximum voltage) x (VT ratio)

Over Current Residual* 4500 mA

*Available in specific meter models. Refer to Features differentiation matrix for PM5500 / PM5600 / PM5700 series, page 20 for the
availability. For over current residual alarms, the maximum setpoint value is limited to 4500 mA independent of the toroid turns setting.

NOTE: For toroid used, the pick-up and drop-out values for over current AL1 I5/I6 and over current AL2 I5/I6 should be set within the range
of residual current measurement meeting specified accuracy as mentioned in table Toroid turns setting example, page 46.

Available standard alarms

Your meter has a set of standard alarms.

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NOTE: Some alarms do not apply to all power system configurations. For
example, line-to-neutral voltage alarms cannot be enabled on 3-phase delta
systems. Some alarms use the system type and the VT or CT ratio to
determine the maximum allowed setpoint.

Alarm label Valid range and resolution

Units
ION Setup Display ION Setup Display

Over Phase Current Over Current, Ph 0.000 to 99999.000 0 to 99999 A

Under Phase Current Under Current, Ph 0.000 to 99999.000 0 to 99999 A

Over Neutral Current Over Current, N 0.000 to 99999.000 0 to 99999 A

Over Ground Current Over Current, Gnd 0.000 to 99999.000 0 to 99999 A

Over Voltage L-L Over Voltage, L-L 0.00 to 999999.00 0 to 999999 V

Under Voltage L-L Under Voltage, L-L 0.00 to 999999.00 0 to 999999 V

Over Voltage L-N Over Voltage, L-N 0.00 to 999999.00 0 to 999999 V

Under Voltage L-N Under Voltage L-N 0.00 to 999999.00 0 to 999999 V

Over Active Power Over kW 0.0 to 9999999.0 0 to 9999999 kW

Over Reactive Power Over kVAR 0.0 to 9999999.0 0 to 9999999 kVAR
Over Apparent Power Over kVA 0.0 to 9999999.0 0 to 9999999 kVA

Leading True PF Lead PF, True -1.00 to -0.01 and 0.01 to 1.00 —

Lagging True PF Lag PF, True -1.00 to -0.01 and 0.01 to 1.00 —

Leading Disp PF Lead PF, Disp -1.00 to -0.01 and 0.01 to 1.00 —

Lagging Disp PF Lag PF, Disp -1.00 to -0.01 and 0.01 to 1.00 —

Over Present Active Power Demand Over kW Dmd, Pres 0.0 to 9999999.0 0 to 9999999 kW

Over Last Active Power Demand Over kW Dmd, Last 0.0 to 9999999.0 0 to 9999999 kW

Over Predicted Active Power Demand Over kW Dmd, Pred 0.0 to 9999999.0 0 to 9999999 kW

Over Present Reactive Power Demand Over kVAR Dmd, Pres 0.0 to 9999999.0 0 to 9999999 kVAR

Over Last Reactive Power Demand Over kVAR Dmd, Last 0.0 to 9999999.0 0 to 9999999 kVAR

Over Predicted Reactive Power Demand Over kVAR Dmd, Pred 0.0 to 9999999.0 0 to 9999999 kVAR

Over Present Apparent Power Demand Over kVA Dmd, Pres 0.0 to 9999999.0 0 to 9999999 kVA

Over Last Apparent Power Demand Over kVA Dmd, Last 0.0 to 9999999.0 0 to 9999999 kVA

Over Predicted Apparent Power Demand Over kVA Dmd, Pred 0.0 to 9999999.0 0 to 9999999 kVA

Over Frequency Over Frequency 0.000 to 99.000 Hz

Under Frequency Under Frequency 0.000 to 99.000 Hz

Over Voltage Unbalance Over Voltage Unbal 0 to 99 %

Over Voltage THD Over Voltage THD 0 to 99 %

Phase Loss Phase Loss 0.00 too 999999.00 0 to 999999 —

Over Current AL1, I5* Over Current AL1, I5 3 to 4500 mA

Over Current AL2, I5* Over Current AL2, I5 3 to 4500 mA

Over Current AL1, I6* Over Current AL1, I6 3 to 4500 mA

Over Current AL2, I6* Over Current AL2, I6 3 to 4500 mA

*Available in specific meter models. Refer to Features differentiation matrix for PM5500 / PM5600 / PM5700 series, page 20 for the
availability.

NOTE: For toroid used, the pick-up and drop-out values for over current AL1 I5/I6 and over current AL2 I5/I6 should be set within the range
of residual current measurement meeting specified accuracy as mentioned in table Toroid turns setting example, page 46.

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RCM alarm application

You can choose:
• Any one alarm (AL1 or AL2) for notification and one for operating digital
output.
OR
• Both AL1 and AL2 alarms for notification.
OR
• Both AL1 and AL2 alarms for operating digital output.
Typical dual alarm application for I5 or I6:
NOTE: It may take up to 30 s for RCM values to populate after meter reset or
power-up.

Alarm event
mA for digital
output operation

Alarm event
for
Residual current

notification

Early notification benefit

Time
Over current AL1 Over current AL2
Priority = Low/Med/High Priority = Low/Med/High
Set dig output = None Set dig output = [SET]

Power factor (PF) alarms

You can set up a Leading PF or Lagging PF alarm to monitor when the circuit’s
power factor goes above or below the threshold you specify.
The Leading PF and Lagging PF alarms use the power factor quadrants as the
values on the y-axis, with quadrant II on the lowest end of the scale, followed by
quadrant III, quadrant I, and finally quadrant IV on the highest end of the scale.

Quadrant PF values Lead/Lag

II 0 to -1 Leading (capacitive)

III -1 to 0 Lagging (inductive)

I 0 to 1 Lagging (inductive)

IV 1 to 0 Leading (capacitive)

Leading PF alarm
The Leading PF alarm monitors an over setpoint condition.

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0
IV
-1
I ∆T1
0
III
+1
∆T2
∆T3
II
0
EV1 EV2

A Pickup setpoint ΔT2 Dropout time delay (in seconds)

B Dropout setpoint EV2 End of alarm condition

ΔT1 Pickup delay period (in seconds) ΔT3 Alarm duration (in seconds)

EV1 Start of alarm condition

Lagging PF alarm
The Lagging PF alarm monitors an under setpoint condition.

0
IV ∆T3
-1
I ∆T2
0
III
+1 ∆T1
II
0
EV1 EV2

A Pickup setpoint ΔT2 Dropout time delay (in seconds)

B Dropout setpoint EV2 End of alarm condition

ΔT1 Pickup delay period (in seconds) ΔT3 Alarm duration (in seconds)

EV1 Start of alarm condition

Phase loss alarm

The phase loss alarm is an under setpoint alarm that monitors the voltages on a 3-
phase system and triggers the alarm when one or two phases fall below the
pickup setpoint setting and remain there long enough to satisfy the pickup time
delay period.
When all of the phases rise above the dropout setpoint setting and remain there
long enough to satisfy the dropout time delay period, the alarm condition is set to
OFF.

Logic alarms
A logic alarm is used to monitor up to four different inputs or parameters.
The logic alarm is tripped when the individual state of all the inputs (A, B, C, D)
cause the output (Y) of a logic operation to be true.

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The logic alarm inputs can only be linked using software.

Custom alarms
Custom alarms (Cust1s) are setpoint-driven alarms, similar to the standard (1-
Sec) alarms.
A custom alarm’s input parameters and setpoint subtypes can only be configured
using software.

Custom alarm parameter list

You can configure custom alarms to monitor over and under conditions on a
variety of different parameters.
The pickup setpoint and dropout setpoint limits are set to -999999 to 999999.

Alarm parameter Unit Alarm parameter Unit

Current A A Active Energy Delivered kW

Current B A Active Energy Received kW

Current C A Active Energy Delivered+Received kW

Current N A Active Energy Delivered-Received kW

Current G A Reactive Energy Delivered kVAR

Current Avg A Reactive Energy Received kVAR

Current Unbalance A % Reactive Energy Delivered+Received kVAR

Current Unbalance B % Reactive Energy Delivered-Received kVAR

Current Unbalance C % Apparent Energy Delivered kVA

Current Unbalance Worst % Apparent Energy Received kVA

Voltage A-B V Apparent Energy Delivered+Received kVA

Voltage B-C V Apparent Energy Delivered-Received kVA

Voltage C-A V Input Metering CH 01 Accumulation —

Voltage L-L Avg V Input Metering CH 02 Accumulation —

Voltage A-N V Input Metering CH 03 Accumulation —

Voltage B-N V Input Metering CH 04 Accumulation —

Voltage C-N V Active Power Last Demand kW

Voltage L-N Avg V Active Power Present Demand kW

Voltage Unbalance A-B % Active Power Predicted Demand kW

Voltage Unbalance B-C % Reactive Power Last Demand kVAR

Voltage Unbalance C-A % Reactive Power Present Demand kVAR

Voltage Unbalance L-L Worst % Reactive Power Predicted Demand kVAR

Voltage Unbalance A-N % Apparent Power Last Demand kVA

Voltage Unbalance B-N % Apparent Power Present Demand kVA

Voltage Unbalance C-N % Apparent Power PredicatedDemand kVA

Voltage Unbalance L-N Worst % Current A Last Demand A

Active Power A kW Current A Present Demand A

Active Power B kW Current A Precidated Demand A

Active Power C kW THD Current A %

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Alarm parameter Unit Alarm parameter Unit

Active Power Total kW THD Current B %

Reactive Power A kVAR THD Current C %

Reactive Power B kVAR THD Current N %

Reactive Power C kVAR THD Current G %

Reactive Power Total kVAR thd Current A %
Apparent Power A kVA thd Current B %

Apparent Power B kVA thd Current C %

Apparent Power C kVA thd Current N %

Apparent Power Total kVA thd Current G %

Frequency Hz Min Freq Hz

Temperature °C Max Active Power A kW

Max Total Demand Distortion %

Max Freq Hz

Disturbance (sag/swell) alarms

The disturbance (sag/swell) alarms is applicable only in PM5650 / PM5760 /
PM5761 meter models.
The meter monitors system’s voltage for sags or swell events. It reports the
disturbance magnitude and timestamp when the event occurs.
You must configure voltage level, sag limit, swell limit and hysteresis for these
alarms to function.
Your meter has two disturbance alarms:

Alarm label Description

Sag Alarm Disturbance alarm triggered due to sag events

Swell Alarm Disturbance alarm triggered due to swell events

Alarm priorities
Each alarm has a priority level that you can use to distinguish between events that
require immediate action and those that do not require action.

Alarm priority Alarm display notification and recording method

Alarm LED Alarm icon Alarm details Alarm logging

High Blinks while the alarm is Blinks while the alarm is Click Details to display Recorded in alarm log.
active. active. Alarm icon remains what caused the alarm to
displayed until pickup or drop off. Click
acknowledged. Ack to acknowledge the
alarm.
Medium Blinks while the alarm is Blinks while the alarm is Click Details to display Recorded in alarm log.
active. active. what caused the alarm to
pickup or drop off.

Low Blinks while the alarm is Blinks while the alarm is Click Details to display Recorded in alarm log.
active. active. what caused the alarm to
pickup or drop off.

None No activity None None Recorded in event log only.

NOTE: The alarm LED notification only occurs if the alarm / energy pulsing
LED is configured for alarming.

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Multiple alarm considerations

If multiple alarms with different priorities are active at the same time, the display
shows the alarms in the order they occurred.

Alarm setup overview

You can use the meter display or ION Setup to configure unary, digital or standard
(1-Sec) alarms. To configure logic and custom alarms, you must use ION Setup.
If you make changes to the basic power meter setup, all alarms are disabled to
prevent undesired alarm operation. If you configure Standard or Custom alarm
setpoints using the display, any decimals previously configured using ION Setup
are lost.

NOTICE
UNINTENDED EQUIPMENT OPERATION
• Verify all alarm settings are correct and make adjustments as necessary.
• Re-enable all configured alarms.
Failure to follow these instructions can result in incorrect alarm functions.

Built-in error-checking
ION Setup dynamically checks incorrect setup combinations. When you enable an
alarm, you must set up the pickup and dropout limits to acceptable values first in
order to exit the setup screen.

Setting up alarms using the display

You can use the display to create and set up standard (1-Sec), unary, digital and
disturbance alarms, and to configure logic and custom alarms after they are
created in ION Setup.
NOTE:
• You must use ION Setup to create logic and custom (Cust1s) alarms.
After the alarm is created, you can use ION Setup or the display to modify
the alarm parameters.
• It is recommended that you use ION Setup to configure standard (1-Sec)
alarms. ION Setup supports a higher resolution to allow you to specify
more decimal places when setting up the pickup setpoint and dropout
setpoint values for certain measurements.
1. Navigate to the alarms setup menu screens and select the alarm you want to
set up.
2. Configure the setup parameters as explained in the different alarm setup
sections.
NOTE: If you use ION Setup to program decimal values on a standard (1-
Sec) alarm, do not use the meter display to make subsequent changes to
any alarm parameters (including enable/disable), as doing so will cause
removal of all decimals previously programmed through ION Setup.
3. Click Yes to save the changes to the meter when prompted.

Setting up alarms using ION Setup

You can use ION Setup to create and set up alarms.
1. Start ION Setup and connect to your meter.
2. Open the Alarming screen.

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3. Select the alarm you want to configure and click Edit.

4. Configure the setup parameters as explained in the different alarm setup
sections.
See the ION Setup Device Configuration guide for more information.

Unary alarm setup parameters

Configure the unary alarm setup parameters as required.
ION Setup controls are shown in parentheses.

Setting Option or range Description

Enable Yes (checked) or No (cleared) This enables or disables the alarm.

Priority High, Medium, Low, None This sets the alarm priority and notification
options.

Select Dig Output (Outputs) None Select the digital output(s) you want to
control when the alarm is triggered.
Digital Output D1

Digital Output D2

Digital Output D1 & D2

Behaviour Normal Select the required behaviour mode

Timed NOTE: When you select Normal value,

Digital Output is not triggered
Coil Hold

Digital alarm setup parameters

Configure the digital alarm setup parameters as required.
ION Setup controls are shown in parentheses.

Setting Option or range Description

Enable Yes (checked) or No (cleared) This enables or disables the alarm.

Priority High, Medium, Low, None This sets the alarm priority and notification
options.

Pickup Setpoint (Setpoint Pickup) On, Off Use this setting to control when to trip the
alarm, based on the state of the digital input
(On or Off).

Pickup Time Delay (Delay) 0 to 999999 This specifies the number of seconds the
digital input must be in the alarm pickup
state before the alarm is tripped.

Dropout Time Delay (Setpoint Dropout 0 to 999999 This specifies the number of seconds the
Delay) digital input must be out of the alarm pickup
state before the alarm turns off.
Select Dig Output (Outputs) None Select the digital output(s) you want to
control when the alarm is triggered.
Digital Output D1

Digital Output D2

Digital Output D1 & D2

Standard (1-Sec) alarm setup parameters

Configure the standard alarm setup parameters as required.
ION Setup controls are shown in parentheses.

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NOTE: It is recommended that you use ION Setup to configure standard

(1-Sec) alarms. ION Setup supports a higher resolution to allow you to specify
more decimal places when setting up the pickup setpoint and dropout setpoint
values for certain measurements.

Setting Option or range Description

Enable Yes (checked) or No (cleared) This enables or disables the alarm.

Priority High, Medium, Low, None This sets the alarm priority and notification
options.

Pickup Setpoint mA (Pickup Limit) Varies depending on the standard alarm you This is the value (magnitude) you define as
are setting up the setpoint limit for triggering the alarm. For
“over” conditions, this means the value has
gone above the Pickup limit. For “under”
conditions, this means the value has gone
below the Pickup limit.

Pickup Time Delay (Delay) 0 to 999999 This specifies the number of seconds the
signal must stay above the pickup setpoint
(for “over” conditions), or below the pickup
setpoint (for “under” conditions) before the
alarm is tripped.

Dropout Setpoint mA (Dropout Limit) Varies depending on the standard alarm you This is the value (magnitude) you define as
are setting up the limit for dropping out of the alarm
condition. For “over” conditions, this means
the value has gone below the Dropout limit.
For “under” conditions, this means the value
has gone above the Pickup limit.

Dropout Time Delay (Delay) 0 to 999999 This specifies the number of seconds the
signal must stay below the dropout setpoint
(for “over” conditions), or above the dropout
setpoint (for “under” conditions) before the
alarm condition is ended.
PU Set Point Lead/Lag (Lead, Lag) Lead or Lag Applies to PF (power factor) alarms only.
Use this to set the PF value and quadrant to
set the pickup setpoint for an over PF
condition (PF Leading) or under PF
condition (PF Lagging).

DO Set Point Lead/Lag (Lead, Lag) Lead or Lag Applies to PF (power factor) alarms only.
Use this to set the PF value and quadrant to
set the dropout setpoint for an over PF
condition (PF Leading) or under PF
condition (PF Lagging).

Select Dig Output (Outputs) None Select the digital output(s) you want to
control when the alarm is triggered.
Digital Output D1

Digital Output D2

Digital Output D1 & D2

Setting up logic alarms using ION Setup

Use ION Setup to configure logic alarms.
NOTE: You must first configure the alarms you want to use as inputs to a logic
alarm. For example, if you use a standard (1-Sec) alarm as one of the inputs,
you must set up its setpoint pickup, dropout and delay parameters.
1. Select the logic alarm you want to set up, then click Edit.
2. Select the alarms you want to use as inputs to the logic alarm.
3. Click the double-arrow button to move the selected alarm(s) to the Selected
(max 4) box, then click OK.
4. Configure the rest of the alarm setup parameters.
5. Click OK then Send to save your changes to the meter.

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Logic alarm setup parameters

Configure the logic alarm setup parameters as required.

Setting Option or range Description

Enable Yes (checked) or No (cleared) This enables or disables the alarm.

Label Logic Alarm 1 to Logic Alarm 10 ION Setup lets you modify the default label so it more clearly
(default labels) identifies your logic alarm. You can only use letters, numbers and
underscores. Spaces are not allowed.

Type AND Output of AND operation is True only if all inputs are True.

NAND Output of NAND operation is True if one or more inputs are False.

OR Output of OR operation is True if one or more inputs are True.

NOR Output of NOR operation is True only if all inputs are False.

XOR Output of XOR operation is True if only one input is True, and all
other inputs are False.

Priority High, Medium, Low, None This sets the alarm priority and notification options.

Select Dig Output (Outputs) None, Select the digital output(s) you want to control when the alarm is
triggered.
Digital Output D1,

Digital Output D2,

Digital Output D1 & D2

Logic alarm setup error prompts

Both the meter and ION Setup have error-checking provisions, and alert you with
an error message if there is an error in the logic alarm setup.
You are alerted if the following actions are attempted:
• The output of a logic alarm is used as an input to itself.
• The same source is duplicated as another input on the same logic alarm.
• The source register used is invalid or is a nonexistent parameter.

Setting up custom alarms using ION Setup

Use ION Setup to configure custom (Cust1s) alarms.
1. Select the custom alarm you want to set up, then click Enable to display the
available setup options.
2. Use the dropdown list to select the parameter you want to set for your custom
alarm.
3. Use the Label box to define a name for your custom alarm.
4. Use the dropdown list to select the setpoint condition you want to monitor:
– Over: Alarm condition occurs when the value goes above the pickup
setpoint setting.
– Under: Alarm condition occurs when the value goes below the pickup
setpoint setting.
– Over (absolute): Alarm condition occurs when the absolute value goes
above the pickup setpoint setting.
– Under (absolute): Alarm condition occurs when the absolute value goes
below the pickup setpoint setting.
5. Configure the rest of the alarm setup parameters.
6. Click OK then Send to save your changes to the meter

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Custom alarm setup parameters

Configure the custom alarm parameters as required.

Setting Option or range Description

Enable Yes (checked) or No (cleared) This enables or disables the alarm.

Setpoint Pickup Varies depending on the custom This is the value (magnitude) you define as the setpoint limit for
alarm you are setting up triggering the alarm. For “over” conditions, this means the value has
gone above the Pickup limit. For “under” conditions, this means the
value has gone below the Pickup limit.

Delay (Setpoint Pickup) 0 to 999999 This specifies the number of seconds the signal must stay above
the pickup setpoint (for “over” conditions), or below the pickup
setpoint (for “under” conditions) before the alarm is tripped.

Setpoint Dropout Varies depending on the custom This is the value (magnitude) you define as the limit for dropping out
alarm you are setting up of the alarm condition. For “over” conditions, this means the value
has gone below the Dropout limit. For “under” conditions, this
means the value has gone above the Pickup limit.

Delay (Setpoint Dropout) 0 to 999999 This specifies the number of seconds the signal must stay below
the dropout setpoint (for “over” conditions), or above the dropout
setpoint (for “under” conditions) before the alarm condition is ended.

Priority High, Medium, Low, None This sets the alarm priority and notification options.

Select Dig Output (Outputs) None, Select the digital output(s) you want to control when the alarm is
triggered.
Digital Output D1,

Digital Output D2,

Digital Output D1 & D2

Setting up disturbance alarms using display

The disturbance (sag/swell) alarms is applicable only in PM5650 / PM5760 /
PM5761 meter models.
NOTE: Before you enable sag/swell alarm, make sure you configure sag/swell
setup parameters as mentioned in Table Sag and swell setup parameters
available using the display, page 193.
You can use the display to configure the disturbance alarms.
1. Navigate to Maint > Setup.
2. Enter the setup passcode (default is “0”),then press OK.
3. Navigate to Alarm > Dist.
4. Move the cursor to point to Sag Alarm or Swell Alarm you want to modify,
then press Edit.
5. Modify the parameters as required, then press OK.
6. Press the up arrow to exit. Press Yes to save your changes.

Sag alarm/Swell alarm setup parameters available using the display

Parameter Values Description

Enable Yes, No This enables or disables the alarm

Priority High, Medium, Low, This sets the alarm priority and notification options
None
Select Dig Output None Select the digital output(s) you want to control when the alarm is triggered

Digital Output D1

Digital Output D2

Digital Output D1 & D2

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LED alarm indicator

You can use the meter’s alarm / energy pulsing LED as an alarm indicator.
When set to detect alarms, the LED blinks to indicate an alarm condition.
NOTE: The alarm / energy pulsing LED on the PM5561 / PM5661 / PM5761 is
permanently set for energy pulsing and cannot be used for alarms.

Configuring the LED for alarms using the display

You can use the meter display to configure the alarm / energy pulsing LED for
alarming.
NOTE: The alarm / energy pulsing LED on the PM5561 / PM5661 / PM5761 is
permanently set for energy pulsing and cannot be used for alarms.
1. Navigate to the LED setup menu screen.
2. Set the mode to Alarm, then press OK.
3. Press the up arrow to exit. Press Yes to save your changes.

Configuring the LED for alarms using ION Setup

You can use ION Setup to configure your meter’s LED for alarming.
NOTE: The alarm / energy pulsing LED on the PM5561 / PM5661 / PM5761 is
permanently set for energy pulsing and cannot be used for alarms.
1. Open ION Setup and connect to your meter. See the ION Setup Help for
instructions.
2. Navigate to I/O configuration > Energy Pulsing.
3. Select Front Panel LED and click Edit.
4. Set the control mode to Alarm.
5. Click Send to save your changes.

Alarm display and notification

The meter notifies you when an alarm condition is detected.

Alarm icon
When a low, medium or high priority alarm is tripped, this symbol appears at the
top right corner of the display screen, indicating that an alarm is active:

For high priority alarms, the alarm icon remains displayed until you acknowledge
the alarm.

Alarm / energy pulsing LED

If configured for alarming, the alarm / energy pulsing LED also flashes to indicate
the meter has detected an alarm condition.

Alarm screens
You can use the display buttons to navigate to the alarm setup or display screens.

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Active alarms
When a pickup event occurs, the active alarm list appears on the meter display’s
Active Alarms screen. Press Detail to see more event information.

Alarm details
Details about the alarms can be viewed using:
• the active alarms (Active), alarm history (Hist), alarm counters (Count) and
unacknowledged alarms (Unack) screens on the meter display, or
• the Active Alarms and Alarm History screens on the meter webpages.

Email on alarm
You can configure the meter to send an email or email-to-text message when
alarm conditions are detected, and set the alarm types and priorities that trigger
the email.
Both the email and the text messages provide the label and the address of the
meter’s main webpage.
• The text message notifies you that there is an alarm condition. You can then
view the active alarms on the meter webpages for details.
• The email message contains additional information about the alarm condition,
such as the alarm name, type, value, priority, and date and time.
In addition, if the connection to the email server is lost, the meter sends a
message once the connection is reestablished so you can check if you missed
any alarm notifications.

Example email

Implementation and default configuration

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
The email on alarm feature is disabled by default.

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Use the meter’s webpages to enable the feature, configure up to 3 email or email-
to-text addresses and set up related parameters.

Email on alarm examples

There are some differences between the email and email-to-text message
functionality for the email on alarm feature.

Overview of the email on alarm feature: email

A A new alarm occurs on the meter.
B The meter starts counting the email hold time and the maximum emails per
message.

C When the email hold time or the maximum emails per message is reached,
whichever is first, the meter sends an email with the details for all alarms
that have occurred since the first alarm.

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Overview of the email on alarm feature: email-to-text

A A new alarm occurs on the meter. The meter sends a text message to
inform you of the alarm.

B The meter starts counting the email hold time and the maximum emails per
message. No new texts are sent for alarms that occur during this period.

C When the email hold time or the maximum emails per message is reached,
whichever is first, the meter sends an email with the details for all alarms
that have occurred since the first alarm.

Configuring the email on alarm feature using the webpages

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
Use the meter webpages to configure the email on alarm feature.
In order to configure the feature, you need the connection information for your
SMTP server, available from your network administrator.
NOTE: The email is sent in the language set for the Product Master or
Administrator account on the meter webpages.
1. Login to the meter webpages.
2. Based on your meter firmware version, click Settings > Email On Alarm
Settings OR click Settings > Communication > Email On Alarm Settings.
3. Configure one or more email addresses to send the alarm notification to.
a. Click Yes to enable that email address.
b. Select Email or Text from the Email/Text list.
c. Type a valid email address in the Email Address field.
NOTE: To receive text notifications, you must enter the email-to-text
address in the correct format. Contact your mobile provider for the
correct format for your mobile device.
4. Configure the types of alarms you want to receive notifications for.
– Click Yes beside the alarm priorities that you want to receive notifications
for: High, Medium and Low.
– Click Yes beside the types of alarms you want to receive notifications for:
Pickup, Dropout and Diagnostic.
5. Configure the SMTP server parameters.

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6. Click Send Test Email to validate the email on alarm configuration.

If configured correctly, you will receive an email or text informing you that you
successfully configured the email settings.
7. Configure the advanced email on alarm parameters, if required.
NOTE: You can click Defaults to reset the advance parameters to their
default values.
Email on alarm SMTP server parameters available using the webpages

Parameter Values Description

SMTP Server IP address — Enter the IP address of the SMTP server used to send the email, available from
your network administrator

SMTP Port Number — The port on the SMTP server that the meter the email to

SMTP Server Requires Yes / No Click Yes if the SMTP server requires login then type in the username and
Login password for the server

Email on alarm advanced parameters available using the webpages

Parameter Values Description

Max Alarms per Email 1 – 60 The maximum number of alarms the meter accumulates before sending an email.
After the meter accumulates the maximum number, it sends an email even if the
max email hold time has not elapsed.

Max Email Hold Time 1 – 300 The maximum time, in seconds, that the meter waits before sending an email.
After the max email hold time elapses, the meter sends any accrued alarms even
if there are less than the Max Alarms per Email.

Server Connection 30 – 600 The maximum time, in seconds, that the meter tries to connect to the SMTP
Timeout server.
Email Retry Attempts 1 – 100 The number of times the meter tries to send an email if the first attempt is
unsuccessful.

Active alarms list and alarm history log

Each occurrence of a low, medium or high priority alarm is stored in the active
alarms list and recorded in the alarm history log.
The active alarm list holds 40 entries at a time. The list works as a circular buffer,
replacing old entries as new entries over 40 are entered into the active alarms list.
The information in the active alarms list is volatile and reinitializes when the meter
resets.
The alarm history log holds 40 entries. The log also works as a circular buffer,
replacing old entries with new entries. The information in the alarm history log is
nonvolatile and is retained when the meter resets.

Viewing active alarm details using the display

When an alarm condition becomes true (alarm = ON), the alarm is displayed on
the active alarms screen.
Alarms are displayed sequentially in the order of their occurrence, regardless of
priority. The alarm details show the date and time of the alarm event, the type of
event (for example, pickup or unary), which phase the alarm condition was
detected on, and the value that caused the alarm condition.
NOTE: Alarm details are not available if the alarm priority is set to None.
The alarm details (for low, medium and high priority alarms) are also recorded in
the alarm history log.
1. Navigate to Alarm > Active.
2. Select the alarm you want to view (the latest ones appear on top).

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3. Press Detail.
NOTE: For unacknowledged high priority alarms, the Ack option appears
on this screen. Press Ack to acknowledge the alarm, or return to the
previous screen if you do not want to acknowledge the alarm.

Viewing alarm history details using the display

The alarm history log keeps a record of active alarms and past alarms.
When an active alarm condition becomes false (alarm = OFF), the event is
recorded in the alarm history log and alarm notification (alarm icon, alarm LED) is
turned off.
Alarms are displayed sequentially in the order of their occurrence, regardless of
priority. The alarm details show the date and time of the alarm event, the type of
event (for example, dropout or unary), which phase the alarm condition was
detected on, and the value that caused the alarm condition to turn ON or OFF.
NOTE: Alarm details are not available if the alarm priority is set to None.
1. Navigate to Alarm > Hist.
2. Select the alarm you want to view (the latest ones appear on top).
3. Press Detail.
NOTE: For unacknowledged high priority alarms, the Ack option appears
on this screen. Press Ack to acknowledge the alarm, or return to the
previous screen if you do not want to acknowledge the alarm.

Viewing alarms counters using the display

Every occurrence of each type of alarm is counted and recorded in the meter.
NOTE: The alarm counters roll over to zero after reaching the value 9999.
1. Select Alarm > Count.
The Alarms Counter screen displays.
2. Scroll through the list to view the number of alarm occurrences for each type
of alarm.

Acknowledging high-priority alarms using the display

You can use the meter display to acknowledge high-priority alarms.
1. Navigate to Alarm > Unack.
2. Select the alarm you want to acknowledge.
3. Press Detail.
4. Press Ack to acknowledge the alarm.
5. Repeat for other unacknowledged alarms.

Resetting alarms using ION Setup

Use ION Setup to reset alarms.
You can also reset alarms using the meter display.
1. Connect to your meter in ION Setup.
2. Open the Meter Resets screen.

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3. Select the alarm parameters to clear and click Reset.

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Multi-tariffs
Multi-tariff
The multi-tariff feature allows you to set up different tariffs for storing energy
values.
The energy values for different tariffs are stored in registers that correspond to
each of those tariffs.

Multi-tariff example
The multi-tariff feature can be used when a utility has set up tariff schedules with
different rates based on what day or time of day energy is consumed.

Power

Time

Cost

Tariff energy containers

T1 T2 T3 T4

T1 T2 T3 T4

In the above illustration, the area under the power curve equals the energy
consumed.
Typically, the utility sets tariff schedules so the cost of energy is higher during high
demand or high energy consumption times. How these “tariff energy containers”
are configured determines how fast these containers fill, which correlates to
increasing energy costs. The price per kWh is lowest at tariff T1 and highest at
tariff T2.

Multi-tariff implementation
The meter supports configuration of up to 8 different tariffs to measure and
monitor energy usage that can be used in billing or cost applications.
There are different tariff modes you can use to determine what tariff is applied and
when: Command mode, Time of Day mode, and Input mode.

Command mode overview

You can use command mode to send a Modbus command to the device which
sets the active tariff.
The active tariff is applied to the measured energy until you send another Modbus
command that sets a different tariff.

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Search for your meter’s Modbus register list at www.se.com to download the
Modbus map.

Time of day mode overview

You can use time of day mode to create a tariff schedule that specifies where the
meter stores energy or input metered data, based on the time of year (month,
day), the type of day (every day, weekend, weekday or a specific day of the week),
or time of day.
The data collected from the different tariffs can then be used in energy audits or
similar costing and budget planning purposes.

Time of day mode tariff validity

A valid time of day tariff has certain conditions and limitations:
• Each tariff must cover a unique time period (tariffs cannot overlap), but there
can be periods with no tariff.
• Any number of tariffs, from none to the maximum number of tariffs, can be
applied.
• Time of day tariffs do not adjust for daylight savings time.
• Time of day tariffs include February 29th in leap years (however, it is not
recommended to have February 29th as a start or end date, as that tariff
would be invalid for non-leap years.
• Except for leap years, tariff dates are not year-specific; if you wanted to
create a tariff that starts on the first Monday in August, you need to enter the
date for that year, then manually update the tariff information for the
subsequent years.
Your device performs validation checks as you enter tariff information; it prompts
you to change the information that you have entered or set the tariff to disabled if
the tariff configuration is invalid. These checks can include:
• Start and end times must be different (for example, you cannot create a tariff
that starts at 02:00 and also ends at 02:00).
• Start time can only be earlier than end time for tariffs that are applied every
day. You can create a daily tariff that starts at 06:00 and ends at 02:00, but
these times are only valid for the Everyday tariff and invalid for the other tariff
types.
• Start day must be earlier than end day if the days are in the same month. You
cannot create a tariff that starts June 15 and ends June 12.

Time of day tariff creation methods

You can create time of day tariffs using one of two methods, or a combination of
these methods.
The two methods of creating tariffs are:
• Time of year tariffs divide the year into multiple sections (usually seasons),
where each section has one or more day types. For example, an eight tariff
configuration using this method could have Spring, Summer, Fall and Winter
seasons that also use different weekend and weekday tariffs.
• Daily tariffs can divide days by day of the week, a weekday, a weekend, or
every day, and can specify the time of day. For example, an eight tariff
configuration could have every day in the year divided into three-hour tariff
periods or could have four tariffs for weekends and four tariffs for weekdays.
You can combine these methods if, for example you wanted to create a tariff that
applies on Mondays from January 1 to June 30, from 09:00 to 17:00. However,
since only one tariff can be applied at any time, you cannot use an everyday or
weekday tariff type because you already specified a tariff for the time periods
09:00 to 17:00.

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Depending on how you configure the tariffs and the maximum number of tariffs
supported by your meter, you may not be able to assign tariffs for the entire year,
potentially leaving time gaps that do not have any tariff assigned to them.

Input mode overview

You can use input mode to have the digital inputs of the device set to know which
tariff is applied to the energy that is presently being consumed.
The number of different tariffs that can be applied is determined by the number of
available digital inputs and the total number of tariffs supported by your device.

Digital input assignment for input control mode

You need to assign one or more digital inputs with non-exclusive associations to
define the active tariff.
If a digital input is used for multi-tariff, it cannot be used for an exclusive
association (such as Demand Sync or Input Metering), but digital inputs can be
shared with a non-exclusive association (such as Alarms). To make a digital input
available for setting tariffs, any conflicting associations must be manually removed
at the source of the original association.
You cannot configure any digital input tariff if digital input 1 is not available for
association. Likewise, digital input 2 must be available to select more than two
tariffs.
The status of the digital inputs is used to calculate the binary value of the active
tariff, where off = 0 and on = 1. The calculation of the number of tariffs value can
differ, depending on the number of digital inputs that can be selected (i.e., inputs
that can be associated with multi-tariff).

Digital input requirements for required number of tariffs

Applicable for PM5650 meter model and PM5500 series except PM5570

Number of Digital inputs required

tariffs required
Configuration 1 Configuration 2

1 — 1 (digital input 1)

2 1 (digital input 1) 2 (digital input 1 and 2)

3 — 2 (digital input 1 and 2)

4 2 (digital input 1 and 2) 3 (digital input 1, 2 and 3)

5 — 3 (digital input 1, 2 and 3)

6 — 3 (digital input 1, 2 and 3)

7 — 3 (digital input 1, 2 and 3)

8 3 (digital input 1, 2 and 3) 4 (digital input 1, 2, 3 and 4)

Applicable for PM5570 / PM5660 / PM5661 / PM5760 / PM5761 meter models

Number of Digital inputs required

tariffs required
Configuration 1 Configuration 2

1 — 1 (digital input 1)

2 1 (digital input 1) 2 (digital input 1 and 2)

3 — 2 (digital input 1 and 2)

4 2 (digital input 1 and 2) 2 (digital input 1 and 2)

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Configuration 1: 8 tariff assignment using 3 digital inputs

Applicable for PM5650 meter model and PM5500 series except PM5570
NOTE: There is no inactive tariff with this configuration.

Tariff Digital input 4 Digital input 3 Digital input 2 Digital input 1

T1 N/A 0 0 0
T2 N/A 0 0 1
T3 N/A 0 1 0
T4 N/A 0 1 1
T5 N/A 1 0 0
T6 N/A 1 0 1
T7 N/A 1 1 0
T8 N/A 1 1 1

Configuration 1: 4 tariff assignment using 2 digital inputs

Applicable for PM5570 / PM5660 / PM5661 / PM5760 / PM5761 meter models
NOTE: There is no inactive tariff with this configuration.

Tariff Digital input 2 Digital input 1

T1 0 0
T2 0 1
T3 1 0
T4 1 1

Configuration 2: 8 tariff assignment using 4 digital inputs

Applicable for PM5650 meter model and PM5500 series except PM5570
NOTE: Digital input configuration 0000 means there are no active tariffs (all
tariffs are disabled).
NOTE: Any configuration above T8 (i.e., 1001 and higher) is invalid and
therefore ignored by the meter (the active tariff does not change).

Tariff Digital input 4 Digital input 3 Digital input 2 Digital input 1

None 0 0 0 0
T1 0 0 0 1
T2 0 0 1 0
T3 0 0 1 1
T4 0 1 0 0
T5 0 1 0 1
T6 0 1 1 0
T7 0 1 1 1
T8 1 0 0 0

Configuration 2: 3 tariff assignment using 2 digital inputs

Applicable for PM5570 / PM5660 / PM5661 / PM5760 / PM5761 meter models
NOTE: Digital input configuration 0000 means there are no active tariffs (all
tariffs are disabled).

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Tariff Digital input 2 Digital input 1

None 0 0
T1 0 1
T2 1 0
T3 1 1

Tariff setup
You can change tariffs and the tariff mode using the display and/or ION Setup.
You can change the tariff mode using the display. You can configure input mode
and time of day mode using the display or ION Setup. It is recommended that you
use ION Setup to configure time of day mode.
The active tariff is controlled based on the tariff mode.
• When the meter is set to command mode for tariffs, the active tariff is
controlled by Modbus commands sent from your energy management system
or other Modbus master.
• When the meter is set to input mode for tariffs, the active tariff is controlled by
the status of the digital inputs.
• When the meter is set to time of day mode for tariffs, the active tariff is
controlled by the day type, the start and end times, and the start and end
dates.

Time of day mode tariff configuration considerations

The time of day tariff is not a calendar; the meter does not calculate the
corresponding day of the week to a specific date, but February 29th is considered
a valid date if you are programming the meter during a leap year.
When you enter tariff times using the display, be aware that the displayed minute
value includes the entire minute. For example, an end time of 01:15 includes the
time from 01:15:00 through 01:15:59. To create a tariff period that starts right after
this, you must set the next tariff’s start time to 01:16. Although it may appear that
there is a gap between these tariffs, there is not.
NOTE: You must always set the tariff times to UTC (GMT, Greenwich Mean
Time), not local time. The GMT Offset (h) setup parameter does not apply to
tariff times.

Input mode tariff configuration considerations

Digital inputs are available for tariffs if they are not used, or if they are only
associated with alarms (Normal). To make a digital input available, you must
manually disconnect the conflicting association before configuring tariffs.
NOTE: You must always set the tariff times to UTC (GMT, Greenwich Mean
Time), not local time. The GMT Offset (h) setup parameter does not apply to
tariff times.
To configure the tariffs using ION Setup, see the “PM5500 / PM5600 / PM5700”
topic in the ION Setup online help or in the ION Setup device configuration guide,
available for download at www.se.com.

Configuring input mode tariffs using the display

Use the display to configure input mode tariffs. You can also configure input mode
tariffs using ION Setup.
You cannot configure any digital input tariff if digital input 1 is not available for
association. Likewise, digital input 2 must be available to select more than two
tariffs.

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The status of the digital inputs is used to calculate the binary value of the active
tariff, where off = 0 and on = 1. The calculation of the number of tariffs value can
differ, depending on the number of digital inputs that can be selected (i.e., inputs
that can be associated with multi-tariff).
1. Navigate to Maint > Setup.
2. Enter the setup passcode (default is “0”), then press OK.
3. Navigate to Meter > Tariff.
4. Select Mode and press Edit.
5. Press + or - to change the setting to Input, then press OK.
NOTE: If a digital input association error prompt displays, you must exit
from the tariff setup screens and remove the digital input association.
6. Navigate to Tariffs, then press Edit.
7. Press + or - to change the number of tariffs you want to set up and press OK.
The maximum number of tariffs that you can apply is determined by the
number of available digital inputs.
8. Navigate to Inputs, then press Edit.
If applicable, press + or - to change how many digital inputs you want to use
to control which tariff is selected (active). Press OK.
9. Press the up arrow to exit, then Yes to save your changes.

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Measurements
Instantaneous measurements
The meter provides highly accurate 1-second measurements.
These measurements include true RMS, per phase and total for:
• 3-phase voltage (line-to-line, line-to-neutral)
• 3-phase current, neutral and ground current
• Active (kW), reactive (kVAR) and apparent (kVA) power
• True PF (power factor)
• Displacement PF
• System frequency
• Voltage (line-to-line, line-to-neutral) and current unbalance
The voltage and current inputs are continuously monitored at a sampling rate of
128 points per cycle. This amount of resolution helps enable the meter to provide
reliable measurements and calculated electrical values for various commercial,
buildings and industrial applications.

Residual current
Available in specific meter models. Refer to Features differentiation matrix
for PM5500 / PM5600 / PM5700 series, page 20 for the availability.
Residual current is an unintended flow of current to ground typically resulting from
an issue with electrical insulation within a load or connecting wiring.
Residual current may be measured as:
• The sum total of all currents flowing through the phase (and neutral)
conductors
• The current flowing through the Protective Earth (PE) conductor in TT and TN
earthing systems
The RCM meter models can be used to continuously measure residual currents in
an electrical system. The RCM meter models are equipped with two input
channels (I5 and I6) that require specific toroid current sensors. Each RCM
channel is capable of dual alarm configuration allowing a warning alert level and a
higher level over alarm. The residual current measurements are processed once
per second.

WARNING
UNINTENDED OPERATION OR METER DAMAGE
• Do not use this device for critical control or protection applications where
human or equipment safety relies on the operation of the control circuit.
• Do not exceed the specified current through I5 and I6 terminals.
Failure to follow these instructions can result in death, serious injury, or
equipment damage.

Typical applications for meters with RCM capability include:

• Leakage current measurement
• Earth (Ground) current measurement
• Automatic notification and/or digital output operation in event of leakage
current alarm
• Electrical installation reliability profiling

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Energy measurements
The meter provides fully bi-directional, 4-quadrant, Class 0.2S accurate energy
metering.
The meter calculates and stores all accumulated active, reactive and apparent
energy measurements in non-volatile memory:
• Wh, VARh, VAh (delivered and received)
• Wh, VARh, VAh net (delivered - received)
• Wh, VARh, VAh absolute (delivered + received)
Energy registers can be logged automatically on a programmed schedule. All
energy parameters represent the total for all three phases. You can view
accumulated energy from the display.

Configuring the energy scaling using ION Setup

You can use ION Setup to configure the energy scaling. Based on the scaling, the
energy overflow happens upon reaching the threshold value.
1. Start ION Setup.
2. Connect to your meter.
3. Open the Energy Scaling screen.
4. Click Edit to configure the Setup parameters as required.
5. Use the drop-down list to select the parameter you want to set for your
Energy Scaling.
NOTE: If you set Energy Scaling parameter, for which the threshold
value is less than the accumulated energy, the accumulated energy
resets to zero.

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6. Click Send to save your changes to the meter.

Energy Scaling parameters available using the ION Setup

Parameter Values Description

Auto 0 to 9.2233 E The energy value units automatically change, based on the quantity of energy
accumulated, from Kilo to Mega, Mega to Giga, Giga to Tera, Tera to Peta and Peta to Exa.
(Default)
When any one of the energy parameter (delivered or received) exceeds 9.2233 E, all the
energy parameters reset to 0.

Kilo (k) 0 to 999.99 k When any one of the energy parameter (delivered or received) exceeds 999.99 k, all the
energy parameters reset to 0.

Mega (M) 0 to 999.99 M The energy value units automatically change, based on the quantity of energy
accumulated, from Kilo to Mega.

When any one of the energy parameter (delivered or received) exceeds 999.99 M, all the
energy parameters reset to 0.

Giga (G) 0 to 999.99 G The energy value units automatically change, based on the quantity of energy
accumulated, from Kilo to Mega and Mega to Giga.

When any one of the energy parameter (delivered or received) exceeds 999.99 G, all the
energy parameters reset to 0.

Tera (T) 0 to 999.99 T The energy value units automatically change, based on the quantity of energy
accumulated, from Kilo to Mega, Mega to Giga and Giga to Tera.

When any one of the energy parameter (delivered or received) exceeds 999.99 T, all the
energy parameters reset to 0.

Peta (P) 0 to 999.99 P The energy value units automatically change, based on the quantity of energy
accumulated, from Kilo to Mega, Mega to Giga, Giga to Tera and Tera to Peta.

When any one of the energy parameter (delivered or received) exceeds 999.99 P, all the
energy parameters reset to 0.

Exa (E) 0 to 9.2233 E The energy value units automatically change, based on the quantity of energy
accumulated, from Kilo to Mega, Mega to Giga, Giga to Tera, Tera to Peta and Peta to Exa.

When any one of the energy parameter (delivered or received) exceeds 9.2233 E, all the
energy parameters reset to 0.

Preset energy
NOTE: Not applicable for MID meter models.
You can input the previous energy values when you replace the meter. Preset
energy value cannot be set more than maximum energy overflow value (9.2233
E).
The preset energy values include active energy (Wh), reactive energy (VARh),
apparent energy (VAh) (delivered and received).

Configuring the preset energy using ION Setup

NOTE: Not applicable for MID meter models.
You can use ION Setup to configure the preset energy values.
1. Start ION Setup.
2. Connect to your meter.
3. Open the Preset Energy screen.
4. Click Edit to configure the Setup parameters as required.
5. From the list, set the Preset Energy value for each parameter.

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6. Click Send to save your changes to the meter.

Preset Energy parameters available using the ION Setup

Parameter Values Description

Active Energy Delivered 0 to 9.2233 E Use this field to enter the preset energy values

Active Energy Received

Reactive Energy Delivered

Reactive Energy Received

Apparent Energy Delivered

Apparent Energy Received

Min/max values
When the readings reach their lowest or highest value, the meter updates and
saves these min/max (minimum and maximum) quantities in non-volatile memory.
The meter’s real-time readings are updated once every 50 cycles for 50 Hz
systems, or once every 60 cycles for 60 Hz systems.

Demand measurements
The meter provides present, last, predicted and peak (maximum) demand, and a
date/timestamp when the peak demand occurred.
The meter supports standard demand calculation methods, including sliding block,
fixed block, rolling block, thermal and synchronized.
Peak demand registers can be reset manually (passcode protected) or logged and
reset automatically on a programmed schedule.
Demand measurements include:
• kW, kVAR, kVA demand total and per phase
• Amps demand average, per phase and neutral (4th CT)
• Demand calculation for pulse input metering (WAGES)

Power demand
Power demand is a measure of average power consumption over a fixed time
interval.
NOTE: If not specified, references to demand are assumed to mean power
demand.
The meter measures instantaneous consumption and can calculate demand using
various methods.

Power demand calculation methods

Power demand is calculated by dividing the energy accumulated during a
specified period by the length of that period.
How the meter performs this calculation depends on the method and time
parameters you select (for example, timed rolling block demand with a 15-minute
interval and 5-minute subinterval).
To be compatible with electric utility billing practices, the meter provides the
following types of power demand calculations:
• Block interval demand

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• Synchronized demand
• Thermal demand
You can configure the power demand calculation method from the display or
software.

Block interval demand

For block interval demand method types, you specify a period of time interval (or
block) that the meter uses for the demand calculation.
Select/configure how the meter handles that interval from one of these different
methods:

Type Description

Timed Sliding Block Select an interval from 1 to 60 minutes (in 1-minute increments). If
the interval is between 1 and 15 minutes, the demand calculation
updates every 15 seconds. If the interval is between 16 and 60
minutes, the demand calculation updates every 60 seconds. The
meter displays the demand value for the last completed interval.

Timed Block Select an interval from 1 to 60 minutes (in 1-minute increments). The
meter calculates and updates the demand at the end of each
interval.
Timed Rolling Block Select an interval and a subinterval. The subinterval must divide
evenly into the interval (for example, three 5-minute subintervals for
a 15-minute interval). Demand is updated at the end of each
subinterval. The meter displays the demand value for the last
completed interval.

Block interval demand example

The following illustration shows the different ways power demand is calculated
using the block interval method. In this example, the interval is set to 15 minutes.

Timed Sliding Block

Demand value is
Calculation updates the average for the
every 15 seconds last completed interval
15-minute interval

Time (sec)
15 30 45 60 . . .

Timed Block

Demand value is
the average for the
Calculation updates at
last completed
the end of the interval
interval

15-minute interval 15-minute interval 15-min

Time
(min)
15 30 45

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Timed Rolling Block

Calculation updates at the end Demand value is

of the subinterval (5 minutes) the average for
the last completed
interval
15-minute interval

Time
(min)
15 20 25 30 35 40 45

Synchronized demand
You can configure the demand calculations to be synchronized using an external
pulse input, a command sent over communications, or the device’s internal real-
time clock.

Type Description

Input synchronized This method allows you to synchronize the demand interval of your meter
demand with an external digital pulse source (such as another meter’s digital
output) connected to your meter's digital input. This helps synchronize
your meter to the same time interval as the other meter for each demand
calculation.
Command This method allows you to synchronize the demand intervals of multiple
synchronized demand meters on a communications network. For example, if a programmable
logic controller (PLC) input is monitoring a pulse at the end of a demand
interval on a utility revenue meter, you can program the PLC to issue a
command to multiple meters whenever the utility meter starts a new
demand interval. Each time the command is issued, the demand readings
of each meter are calculated for the same interval.
Clock synchronized This method allows you to synchronize the demand interval to the meter’s
demand internal real-time clock. This helps you synchronize the demand to a
particular time, typically on the hour (for example, at 12:00 am). If you
select another time of day when the demand intervals are to be
synchronized, the time must be specified in minutes from midnight. For
example, to synchronize at 8:00 am, select 480 minutes.

NOTE: For these demand types, you can choose block or rolling block
options. If you select a rolling block demand option, you need to specify a
subinterval.

Thermal demand
Thermal demand calculates the demand based on a thermal response, which
imitates the function of thermal demand meters.
The demand calculation updates at the end of each interval. You can set the
demand interval from 1 to 60 minutes (in 1-minute increments).

Thermal demand example

The following illustration shows the thermal demand calculation. In this example,
the interval is set to 15 minutes. The interval is a window of time that moves
across the timeline. The calculation updates at the end of each interval.

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99%
90% Last completed
demand interval

% of Load
Time
(minutes)

15-minute next
interval 15-minute
interval

Current demand
The meter calculates current demand using the block interval, synchronized or
thermal demand methods.
You can set the demand interval from 1 to 60 minutes in 1 minute increments (for
example, 15 minutes).

Predicted demand
The meter calculates predicted demand for the end of the present interval for kW,
kVAR, and kVA demand, taking into account the energy consumption so far within
the present (partial) interval and the present rate of consumption.
Predicated demand is updated according to the update rate of your meter.
The following illustration shows how a change in load can affect predicted demand
for the interval. In this example, the interval is set to 15 minutes.

1:00 1:06 1:15

A Beginning of interval E Change in load

B Demand for last completed interval F Predicted demand if load is added

during interval; predicted demand
increases to reflect increased demand
C 15-minute interval G Predicted demand if no load is added
D Partial interval H Time

Peak demand
The meter records the peak (or maximum) values for kWD, kVARD, and kVAD
power (or peak demand).
The peak for each value is the highest average reading since the meter was last
reset. These values are maintained in the meter’s non-volatile memory.
The meter also stores the date and time when the peak demand occurred. In
addition to the peak demand, the meter also stores the coinciding average 3-
phase power factor. The average 3-phase power factor is defined as “demand kW/
demand kVA” for the peak demand interval.

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Input Metering Demand

The input metering channels can be used to measure water, air, gas, electric and
steam utilities (WAGES).
The number of available metering input channels equals the number of unused
digital inputs.
Typical WAGES utility meters have no communications capabilities, but they
usually have a pulse output. The utility meter sends a pulse to its output each time
a preset quantity or amount of (WAGES) energy is consumed or delivered. This
preset quantity or amount is referred to as the pulse weight.
To monitor the utility meter, connect its pulse output to the power meter’s digital
input. Associate the digital input for input metering and configure the input
metering operation mode, pulse weight, consumption units and demand units.

Setting up demand calculations using the display

Use the Demand setup screens to define power demand, current demand or input
metering demand.
Demand is a measure of average consumption over a fixed time interval.
1. Navigate to Maint > Setup.
2. Enter the setup passcode (default is “0”), then press OK.
3. Navigate to Meter > Dmd.
4. Move the cursor to select Power Demand, Current Demand or Input
Demand.

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5. Move the cursor to point to the parameter you want to modify, then press
Edit.

Values Description

Method
Timed Sliding Block Select the appropriate demand calculation method for your needs

Timed Block

Timed Rolling Block

Input Sync Block

Input Sync Roll Block

Cmd Sync Block

Cmd Sync Roll Block

Clock Sync Block

Clock Sync Roll Block

Thermal
Interval
1–60 Set the demand interval, in minutes.

Subinterval
1–60 Applies only to rolling block methods.

Define how many subintervals the demand interval should be equally divided into.

Select Dig Output

None Select which digital output the end of demand interval pulse should be sent to.

Digital Output D1

Digital Output D2

Select Dig Input

None Applies only to input sync methods.

Digital Input S1 Select which digital input is used to sync the demand.

Digital Input S2

Digital Input S3*

Digital Input S4*

Clock Sync Time

0 - 2359 Applies only to clock sync methods (these synchronize the demand interval to the meter’s
internal clock).

Define what time of day you want to synchronize the demand, from the start of the day. For
example, set this setting to 0730 to synchronize demand at 7:30 AM.

*Available in specific meter models. Refer to Features differentiation matrix for PM5500 / PM5600 / PM5700 series, page 20 for the
availability.

6. Modify the parameter as required, then press OK.

7. Move the cursor to point to the next parameter you want to modify, press Edit,
make your changes, then press OK.
8. Press Yes to save your changes.

Power and power factor

The sampled measurements taken at the meter’s voltage and current inputs
provide data for calculating power and power factor.

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In a balanced 3-phase alternating current (AC) power system source, the AC

voltage waveforms on the current-carrying conductors are equal but offset by one-
third of a period (a phase angle shift of 120 degrees between the three voltage
waveforms).

Current phase shift from voltage

Electrical current can lag, lead, or be in phase with the AC voltage waveform, and
is typically associated with the type of load — inductive, capacitive or resistive.
For purely resistive loads, the current waveform is in phase with the voltage
waveform. For capacitive loads, current leads voltage. For inductive loads, current
lags voltage.
The following diagrams show how voltage and current waveforms shift based on
load type under ideal (laboratory) conditions.

Current and voltage in phase (resistive) Current leads voltage (capacitive) Current lags voltage (inductive)

Real, reactive and apparent power (PQS)

A typical AC electrical system load has both resistive and reactive (inductive or
capacitive) components.
Real power, also known as active power (P) is consumed by resistive loads.
Reactive power (Q) is either consumed by inductive loads or generated by
capacitive loads.
Apparent power (S) is the capacity of your measured power system to provide real
and reactive power.
The units for power are watts (W or kW) for real power P, vars (VAR or kVAR) for
reactive power Q, and volt-amps (VA or kVA) for apparent power S.

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+Q
(+kVAR, +kVARh)

Quadrant 2 90° Quadrant 1

PF leading PF lagging
Power factor sign convention: Power factor sign convention:
IEEE = + IEEE = −
IEC = − IEC = +

Reactive power (VAR)

Reactive power (VAR)

Imported/delivered

Imported/delivered
)
Ap

VA
pa

(
er
re

w
nt

po
po

nt
w

re
er

pa
(V

Ap
A)
Active power (W) Active power (W)
Exported/received Imported/delivered
-P +P
(-kW, -kWh) 180° 0° (+kW, +kWh)
Active power (W) Active power (W)

Reactive power (VAR)

Reactive power (VAR)

Exported/received Imported/delivered

Exported/received

Exported/received
A)

Ap
(V

p
ar
er

en
w
po

tp
ow
nt
re

er
pa

(V
Ap

A)
Quadrant 3 Quadrant 4
PF lagging PF leading
Power factor sign convention: Power factor sign convention:
IEEE = − IEEE = +
IEC = − IEC = +
270°

-Q
(-kVAR, -kVARh)

Power flow
Positive real power P(+) flows from the power source to the load. Negative real
power P(-) flows from the load to the power source.

Power factor (PF)

Power factor (PF) is the ratio of real power (P) to apparent power (S).
PF is provided as a number between -1 and 1 or as a percentage from -100% to
100%, where the sign is determined by the convention.
P
PF = —
S

A purely resistive load has no reactive components, so its power factor is 1 (PF =
1, or unity power factor). Inductive or capacitive loads introduce a reactive power
(Q) component to the circuit which causes the PF to become closer to zero.

True PF and displacement PF

The meter supports true power factor and displacement power factor values:
• True power factor includes harmonic content.
• Displacement power factor only considers the fundamental frequency.
NOTE: Unless specified, the power factor displayed by the meter is true power
factor.

Power factor sign convention

Power factor sign (PF sign) can be positive or negative, and is defined by the
conventions used by the IEEE or IEC standards.
You can set the power factor sign (PF sign) convention that is used on the display
to either IEC or IEEE.

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PF sign convention: IEC

PF sign correlates with the direction of real power (kW) flow.
• Quadrant 1 and 4: Positive real power (+kW), the PF sign is positive (+).
• Quadrant 2 and 3: Negative real power (-kW), the PF sign is negative (-).

PF sign convention: IEEE

PF sign is correlates with the PF lead/lag convention, in other words, the effective
load type (inductive or capacitive):
• For a capacitive load (PF leading, quadrant 2 and 4), the PF sign is positive
(+).
• For an inductive load (PF lagging, quadrant 1 and 3), the PF sign is negative
(-).

Power factor register format

The meter provides power factor values in a variety of formats to suit your energy
management software.

Power factor in IEC and lead/lag (IEEE) formats: Float32 and

Int16U registers
The meter provides total power factor in IEC and lead/lag (IEEE) formats in both
Float32 and Int16U data types. You can use these registers to bring power factor
information into third-party software. These registers are interpreted using the
standard IEC and IEEE sign conventions.
NOTE: For information on how to calculate actual power factor values from
the values in Int16U registers, see your meter’s Modbus register list, available
from www.se.com.

Four quadrant power factor information: floating point registers

The meter also provides PF information (including sign and quadrant) in single
floating point registers for each of the PF values (for example, per-phase and total
values for true and displacement PF, and associated minimums and maximums).
The meter performs a simple algorithm to the PF value then stores it in the
appropriate PF register.
The meter and software (such as Power Monitoring Expert or ION Setup) interpret
these PF registers for reporting or data entry fields according to the following
diagram:

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-0.5 +0.5

Quadrant 2 Quadrant 1
-1 ≤ PF < 0 0 ≤ PF ≤ 1

-1 +1

Quadrant 3 Quadrant 4
-1 < PF < 0 0 < PF < 1

-0.5 +0.5

0 to -1 -1 to 0 0 to +1 +1 to 0
PF Value

0 -1 0 +1 0
Quadrant 3 Quadrant 2 Quadrant 1 Quadrant 4

Quadrant 2 Quadrant 3 Quadrant 1 Quadrant 4

-2 -1 0 +1 +2

PF register -2 to -1 -1 to 0 0 to +1 +1 to +2

-2 0

-1.5 +0.5

Quadrant 2 Quadrant 1
-2 ≤ PF register ≤ -1 0 ≤ PF register ≤ 1

-1 +1

Quadrant 3 Quadrant 4
-1 < PF register ≤ 0 2 ≤ PF register < 1

-0.5 +1.5

0 +2

The PF value is calculated from the PF register value using the following formulas:

Quadrant PF range PF register range PF formula

Quadrant 1 0 to +1 0 to +1 PF value = PF register

value
Quadrant 2 -1 to 0 -2 to -1 PF value = (-2) - (PF
register value)

Quadrant 3 0 to -1 -1 to 0 PF value = PF register

value
Quadrant 4 +1 to 0 +1 to +2 PF value = (+2) - (PF
register value)

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Go to www.se.com and search for your meter’s Modbus register list to download a
copy.

Timers
The meter supports an I/O timer, active load timer and an operating timer.
Use the meter display to navigate to the Timer and I/O screens to view timer
information.

Operating Timer
The operating timer (Timer > Oper) keeps track of how long the meter has been
powered up.

Load Timer
The load timer keeps track of how much time the input current exceeds the
specified load timer setpoint current.

I/O timer
The I/O timer shows how long an input or output has been ON.

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Power quality
Power quality measurements
The meter provides complete harmonic distortion metering, recording and real-
time reporting, up to the 63rd harmonic for all voltage and current inputs.
The following power quality measurements are available:
• Individual harmonics (odd harmonics up to 63rd)
• Total harmonic distortion (THD, thd) for current and voltage (line-to-line, line-
to neutral)
• Total demand distortion (TDD)
• K-factor, Crest factor
• Neutral current metering and ground current calculation
The following harmonics data is available on the display:
• Numeric magnitude and angle of the fundamental (first) harmonic.
• Graphical display of the 3rd to 31st harmonics, expressed as a percentage of
the fundamental harmonic.

Harmonics overview
Harmonics are integer multiples of the fundamental frequency of the power
system.
Harmonics information is valuable for power quality analysis, determining properly
rated transformers, maintenance and troubleshooting. Evaluation of harmonics is
required for compliance to system power quality standards such as EN50160 and
meter power quality standards such as IEC 61000-4-30.
Harmonics measurements include per-phase magnitudes and angles (relative to
the fundamental frequency of the phase A voltage) for the fundamental and higher
order harmonics relative to the fundamental frequency. The meter’s power system
setting defines which phases are present and determines how line-to-line or line-
to-neutral voltage harmonics and current harmonics are calculated.
Harmonics are used to identify whether the supplied system power meets required
power quality standards, or if non-linear loads are affecting your power system.
Power system harmonics can cause current flow on the neutral conductor, and
damage to equipment such as increased heating in electric motors. Power
conditioners or harmonic filters can be used to minimize unwanted harmonics.

Voltage crest factor

Crest factor is the ratio of peak to RMS voltage values.
For a pure sinusoidal waveform, crest factor is equal to 1.414. The meter uses the
following equation to calculate crest factor:

C = Crest factor
Vpeak
C= Vpeak = Voltage peak
VRMS
VRMS = Voltage RMS

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K-factor
K-factor relates the heating effect of a distorted current in a transformer to a
sinusoidal current with the same RMS magnitude — it describes a transformer’s
ability to serve non-linear loads without exceeding rated temperature rise limits.
The K-factor is equal to the sum of the squares of the harmonic currents multiplied
by the squares of the harmonic order. The meter uses the following equation to
calculate K-factor:
h
2 2
∑ (Ih x h )
n=1
K=
h 2
∑ Ih
n=1
Where K is the K-factor, h is the harmonic order and Ih is the true RMS current of
harmonic order h.

Total harmonic distortion %

Total harmonic distortion (THD%) is a measure of the total per-phase voltage or
current harmonic distortion present in the power system.
THD% provides a general indication of the quality of a waveform. THD% is
calculated for each phase of both voltage and current.

Total demand distortion

Total demand distortion (TDD) is the per-phase harmonic current distortion against
the full load demand of the electrical system.
TDD indicates the impact of harmonic distortion in the system. For example, if
your system is showing high THD values but a low demand, the impact of
harmonic distortion on your system might be insignificant. However at full load, the
THD value for the current harmonics is equal to TDD, so this could negatively
impact your system.

Harmonic content calculations

Harmonic content (HC) is equal to the RMS value of all the non-fundamental
harmonic components in one phase of the power system.
The meter uses the following equation to calculate HC:

HC = (H2)2 + (H3)2 + (H4)2 ...

THD% calculations
THD% is a quick measure of the total distortion present in a waveform and is the
ratio of harmonic content (HC) to the fundamental harmonic (H1).
By default, the meter uses the following equation to calculate THD%:
HC
THD = -------
- x 100%
H1

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thd calculations
thd is an alternate method for calculating total harmonic distortion that uses the
RMS value for the total harmonic content rather than the fundamental content.
The meter uses the following equation to calculate thd:
HC
thd = x 100
(H1)2 + (HC)2

TDD calculations
TDD (total demand distortion) evaluates the harmonic currents between an end
user and a power source.
The harmonic values are based on a point of common coupling (PCC), which is a
common point where each user receives power from the power source.
The meter uses the following equation to calculate TDD:

TDD = ( (HCIA)2 + (HCIB)2 + (HCIC)2) / (ILoad) x 100

Where ILoad is equal to the maximum demand load on the power system.

Viewing harmonics using the display

You can view harmonics data using the display.
1. Navigate to Harm.
The Harmonics % screen displays:
2. Press the voltage or current harmonics you want to view.

IEEE mode IEC mode Description

V L-L U Line-to-line voltage harmonics data

V L-N V Line-to-neutral voltage harmonics data

Amps I Current harmonics data

TDD/K TDD/K Total demand distortion and K-factor data

Crest Crest Crest factor data

The fundamental (1st) harmonics numeric magnitudes and angles for all
phases are displayed.

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3. Press 3–11, 13–21, or 21–31 to view the graphs for the 3rd to the 11th, 13th
to 21st, or 23rd to 31st harmonics, respectively.
For example, to display the 13th to 21st harmonics screen, press 13–21.

A Phase A B Phase B C Phase C

The vertical axis of the harmonics graph indicates the harmonic’s magnitude
as a percentage of the fundamental harmonic, and is scaled based on the
largest harmonic displayed. At the top of each vertical bar is a marker that
shows the maximum value of the harmonic. If the harmonic is greater than the
fundamental harmonic, this marker is triangular-shaped to show that the
value is out of range.
NOTE: The display screen only shows odd harmonics up to the 31st
harmonic. However, all individual odd and even harmonics data up to the
63rd harmonic is available through communications and software.
Individual harmonics data include current harmonics per phase, neutral
and ground, and voltage harmonics line-to-line, line-to-neutral and neutral
to ground.

Viewing TDD, K-factor and Crest factor data

The meter display provides screens that show TDD, K-factor and Crest factor
values.
NOTE: Your meter’s Modbus map includes registers for harmonics data for
integration into your power or energy management system.
1. Navigate to Harm > TDD/K.
The TDD and K-factor per phase information displays.

Value Description

TDD Total demand distortion

K-F A K factor for phase A

K-F B K factor for phase B

K-F C K factor for phase C

2. Navigate to Harm > Crest.

The Crest factor information displays.

IEEE mode IEC mode Description

V L-L U Crest factor data for line-to-line voltage

V L-N V Crest factor data for line-to-neutral voltage

Amps I Crest factor data for current

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3. Press the up arrow to return to the main display screens.

Viewing THD/thd using the display

You can view THD/thd data using the display.
NOTE: Your meter’s Modbus map includes registers for total harmonic
distortion data for integration into your power or energy management system.
1. Navigate to THD to view the THD/thd Select screen.
2. Press THD to display values that use the calculation method based on the
fundamental harmonic or thd to display values that use the calculation
method based on the RMS value of all harmonics in that phase (including the
fundamental).

IEEE mode IEC mode Description

Amps I Total harmonic distortion data for per phase

and neutral currents.
V L-L U Total harmonic distortion data line-to-line
voltage.

V L-N V Total harmonic distortion data line-to-neutral

voltage.

3. Press the current or voltage THD or thd values you want to view.
The total harmonic distortion percentage values are displayed.
4. Press the up arrow to return to the main display screens.

Waveform capture
Overview of waveform capture
Applicable only in PM5650 / PM5760 / PM5761 meter models.
Your meter is able to record voltage and current waveform information.
Waveform capture information is used to help identify power system disturbances,
which are an increasing concern for industrial plants, hospitals, data centers and
other facilities where the equipment is sensitive to voltage sags and swells.
In addition to measuring and recording numerical values for voltage and current,
your meter can also capture the sinusoidal waveform data. The current and
voltage waveform capture data provides additional information for analysis of the
system’s power quality event.
You can manually trigger waveform capture or configure them to trigger
automatically when there is a power quality event. For waveform capture to trigger
automatically, you must enter your system’s nominal (normal) voltage values, and
then the amount of deviation from the nominal required to trigger waveform
capture.

Waveform capture data storage format

The waveform capture records are stored in the form of COMTRADE files.
The meter can store up to 10 COMTRADE files in its internal FTP server.

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Default waveform capture configuration

Your meter’s waveform capture of sag/swell events is functional once the nominal
values are configured through ION Setup or any tool using the Modbus commands
specified in the register list of PM5xxx model.
Your meter has the following default waveform capture events:

Waveform capture events Description

V1-Sg/Sw
Captures V1, V2, V3 and I1, I2, I3 waveforms during a defined
V2-Sg/Sw
voltage sag or swell event
V3-Sg/Sw

NOTE: The minimum duration between two sag/swell events to record is 3 s.

COMTRADE
COMTRADE stands for COMmon format for TRAnsient Data Exchange defined
by IEC 60255-24, and defines a common format for power quality event
(disturbance) data in order to simplify retrieval, analysis and exchange of
disturbance data between multiple sources and vendors.
COMTRADE is configured as part of the default waveform framework.
COMTRADE records are generated for waveform records triggered by power
quality events or manually.
COMTRADE files can be accessed from the meter’s internal FTP server or
through Modbus TCP (not available on serial), and is composed of two files:

File name extension Description

.cfg Configuration of event data

.dat Event data records per .cfg file

• Data samples of events
• Time stamped digital samples
• Number of entries (depends on sampling rate and sample
duration

By default:
• The meter is configured to generate COMTRADE records for any sag/swell
event.
• The oldest COMTRADE record is overwritten by the newest record when the
COMTRADE limit of 10 files is exceeded.
NOTE: COMTRADE files can only be downloaded using an Ethernet
connection. They cannot be downloaded using serial, modem or Ethernet
gateway connections.
See the COMTRADE and ION technology technical note, available from
www.se.com, for detailed information about COMTRADE file formats.

Configuring waveform capture using ION Setup

You can configure your meter to capture waveforms when it experiences a sag or
swell event or a manual trigger without any events, and to export the waveform
data to COMTRADE files.
NOTE: See your meter’s Modbus register list at www.se.com for the Modbus
mapping information and basic instructions on command interface.
1. Start ION Setup and connect to your meter.
2. Open the Waveform Configuration screen in the Power Quality folder.
3. Click Edit to configure the Setup parameters as required.

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4. Click Send to save your changes to the meter.

Waveform capture parameters available using the ION Setup

Parameter Values Description

Status Enable Enables or disables waveform capture on your meter

Disable
Samples per Cycle Samples per cycle: Select the Samples per cycle based on the requirement
• 128 samples/cycle • Maximum 8 cycles for 128 samples/cycle
• 64 samples/cycle • Maximum 16 cycles for 64 samples/cycle
• 32 samples/cycle • Maximum 32 cycles for 32 samples/cycle
• 16 samples/cycle • Maximum 64 cycles for 16 samples/cycle

Pre/Post allocation: The Pre-cycles can be configured based on the Samples per cycle
• Pre-cycles: Number of cycles • 1 – 8 (for 128 samples/cycle, sum of pre and post cycles must be 8)
that will be captured in • 1 – 16 (for 64 samples/cycle, sum of pre and post cycles must be 16)
waveforms prior to waveform
trigger • 1 – 32 (for 32 samples/cycle, sum of pre and post cycles must be 32)
• Post-cycles : Number of • 1 – 64 (for 16 samples/cycle, sum of pre and post cycles must be 64)
cycles that will be captured in The Post-cycles will be automatically configured based on the Pre-cycles
waveforms post waveform
trigger NOTE: It is recommended for the end user to configure equal number
of pre and post cycles to visualize sag/swell events in waveform.

Mode Circular Select Circular

Configuring waveform capture using the display

You can use the display to configure the waveform capture.
1. Navigate to Maint > Setup.
2. Enter the setup passcode (default is “0”), then press OK.
3. Navigate to WFC.
4. Move the cursor to point to the parameter you want to modify, then press
Edit.
5. Modify the parameters as required, then press OK.
6. Press the up arrow to exit. Press Yes to save your changes.

Waveform capture setup parameters available using the display

Parameter Values Description

Enable Yes, No Enables or disables the waveform capture on your

meter
Samples Per Cycle 128 Select the samples per cycle based on the
requirement
64

32

16
Pre Cycles The pre cycles can be configured based on the Select the pre cycles based on the requirement
samples per cycle
The Post-cycles will be automatically configured
• Maximum 1 – 8 pre cycles for 128 samples per based on the Pre-cycles
cycle
NOTE: It is recommended for the end user to
• Maximum 1 – 16 pre cycles for 64 samples per configure equal number of pre and post
cycle cycles to visualize sag/swell events in
• Maximum 1 – 32 pre cycles for 32 samples per waveform.
cycle • Pre-cycles: Number of cycles that will be
• Maximum 1 – 64 pre cycles for 16 samples per captured in waveforms prior to waveform
cycle trigger
• Post-cycles : Number of cycles that will be
captured in waveforms post waveform
trigger

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Configuring sag/swell using ION Setup

You can configure your meter to monitor sag/swell data as a trigger to capture
waveforms, and to export the waveform data to COMTRADE files.
NOTE: For waveform recording to trigger automatically, enter your system’s
nominal (normal) voltage values and the amount of deviation from the nominal
that is considered a sag or a swell using the Power Quality screen.
1. Start ION Setup and connect to your meter.
2. Open the Voltage Sag/Swell screen in the Power Quality folder.
3. Click Edit to configure the Setup parameters as required.
4. Click Send to save your changes to the meter.

Voltage sag/swell parameters available using the ION Setup

Parameter Values Description

PQ Voltage 100 – 1000000 Set the voltage level to the required value
Level
NOTE: The user must configure the nominal voltage L-L for 3PH3W or L-N for other
power system configurations.

Sag Limit % 1 – 99 Set the sag limit values

NOTE: Sag limit + hysteresis must be ≤100

Swell Limit % 101 – 199 Set the swell limit values

NOTE: Swell limit - hysteresis must be ≥100

Hysterisis % 1 – 100 Set the hysteresis value

The hysteresis is the difference in magnitude between the start and end thresholds for
sag/swell. For example, a hysteresis of 5% means that a sag with a threshold of 90%
needs to reach 95% before the sag is over and a swell with a limit of 110% needs to reach
105% before the swell is over.

Configuring sag/swell using the display

You can use the display to configure sag/swell data as a trigger to capture
waveforms.
1. Navigate to Maint > Setup.
2. Enter the setup passcode (default is “0”), then press OK.
3. Navigate to Dist.
4. Move the cursor to point to the parameter you want to modify, then press
Edit.
5. Modify the parameters as required, then press OK.

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6. Press the up arrow to exit. Press Yes to save your changes.

Sag and swell setup parameters available using the display

Parameter Values Description

Sag Limit 1 – 99 Set the sag limit values in %

NOTE: Sag limit + hysteresis must be ≤100

Swell Limit 101 – 199 Set the swell limit values in %

NOTE: Swell limit - hysteresis must be ≥100

Hysterisis 1 – 100 Set the hysteresis value

The hysteresis is the difference in magnitude

between the start and end thresholds for sag/
swell. For example, a hysteresis of 5% means
that a sag with a threshold of 90% needs to reach
95% before the sag is over and a swell with a limit
of 110% needs to reach 105% before the swell is
over.
PQ Voltage Level 100 – 1000000 Set the system nominal voltage level
NOTE: The user must configure the nominal
voltage L-L for 3PH3W or L-N for other
power system configurations.

Monitoring waveform capture on meter’s webpages

NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
Before you can view waveforms on the meter’s webpages, you need to perform
some basic configuration using ION Setup to enable waveform capture and store
the waveforms in COMTRADE format.

Manual trigger

1. Enable waveform capture on 2. A waveform is captured when 3. View the waveform on the
your meter it is manually triggered using meter’s webpages
Modbus command or ION Setup
Set the status to Enable using ION Setup. Login to the meter webpages.
A COMTRADE record is generated and
saved to your meter’s FTP site. Based on your meter firmware version, click
Monitoring > Waveforms to explore the
waveform data.

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Automatic trigger

1. Enable waveform capture on 2. A waveform is captured when 3. View the waveform on the
your meter a power quality event occurs meter’s webpages
Set the meter’s nominal voltage and sag/ A COMTRADE record is generated and Login to the meter webpages.
swell parameters using ION Setup. saved to your meter’s FTP site.
Based on your meter firmware version, click
Monitoring > Waveforms to explore the
waveform data.

Viewing waveform capture on meter’s webpages

After COMTRADE files are generated by your meter, you can view them using the
webpages.
1. Select the file you want to view from the record dropdown on meter’s
webpages.

Screenshot of the waveform capture on webpages

A. Select the COMTRADE waveform

to view
B. Show / hide parameters
C. View details
D. Zoom in / out

2. Click or tap an individual voltage or current channel in the legend to show or

hide it in the waveform viewer.
– Visible
– Hidden
3. Use the bar at the bottom to zoom in / zoom out on a particular section of the
waveform, or to scan through the waveform with the selected zoom level.

– Draw a window over a particular area to zoom in on that section of the

waveform.
– Drag the selected area to move the zoom across the waveform.
– Drag the start and end points to expand or narrow the zoom.

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4. Hover over or tap a spot on the waveform to view the values associated with
that particular moment in time.

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Maintenance
Maintenance overview
The meter does not contain any user-serviceable parts. If the meter requires
service, contact your local Schneider Electric Technical Support representative.

NOTICE
METER DAMAGE
• Do not open the meter case.
• Do not attempt to repair any components of the meter.
Failure to follow these instructions can result in equipment damage.

Do not open the meter. Opening the meter voids the warranty.

Lost user access

If you lose your meter’s user access (passcode) information, contact your local
Schneider Electric representative for instructions on how to return your meter for
factory reconfiguration.
NOTE: Have your meter’s serial number available for reference.

Diagnostics information
The meter provides you with diagnostics information to help with troubleshooting.
Navigate to Maint > Diag > Info to view the meter model, serial number, date of
manufacture, firmware version (including OS - Operating System and RS - Reset
System), language version, and OS CRC (Cyclic Redundancy Check). The OS
CRC value is a number (Hexadecimal format) that identifies the uniqueness
between different OS firmware versions.
Navigate to Maint > Diag > Meter to view details of the meter status.
Navigate to Maint > Diag > Cl Pwr to view the control power information.
• Non-MID meter models: The Cl Pwr screen displays how many times the
meter lost control power, and the date and time of its last occurrence.
• MID meter models: The Cl Pwr screen displays the Number of Losses, the
Last Power Up and the Last Power Down events with the timestamp.
Navigate to Maint > Diag > Phasor to view the graphical representation of the
power system the meter is monitoring.
Navigate to Maint > Diag > Phasor > Polar to view the numeric magnitude and
angles of all voltage and current phases.
You can access the meter’s maintenance log using the webpages.

Control power (auxiliary power) interruption event

For MID compliant models.
When the meter is in OFF state and control power supply is applied OR when the
meter is in ON state and the control power is cycled:

• If the 4-digit MID/Revenue Lock is enabled, an icon which indicates the

control power loss blinks on the top right corner of the screen.

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• When the meter is in ON state and the control power goes below the
operating range, the meter logs the Last Power Down event with timestamp
before power-off.
• When the meter is in OFF state and the control power is applied, the meter
logs the Last Power Up event with timestamp after power-on.
• When there are multiple events along with control power interruption event,
then the control power interruption event icon blinks taking precedence over
all other icons.
NOTE: The meter displays only the Number of Losses, the Last Power
Down and Last Power Up events. The last 20 control power interruption
event logs (10 Power Down and 10 Power Up events) can be read only
through communication.

Acknowledging control power (auxiliary power) interruption event using the display
For MID compliance on applicable models.
NOTE: When the control power interruption event icon displays on the meter,
the facility manager must assess the reason and its duration.
Use the Cl Pwr screen to acknowledge the control power interruption event.
You can acknowledge (dismiss) the control power interruption event only after
entering the 4-digit MID/Revenue Lock password.
NOTE:
• You cannot acknowledge the alarms and the control power interruption
events at the same time.

• The control power interruption event icon blinks until you

acknowledge the Number of Losses, the Last Power Up and Last
Power Down events.
1. Navigate to Maint > Diag > Cl Pwr.
The Number of Losses, the Last Power Up and Last Power Down events
with the timestamp are displayed on the same page.
2. Press Ack.
3. Enter the Revenue Lock password, then press OK.
NOTE: The default password is 0000.
4. Read the Attention! message on the display and press Yes to acknowledge
or press No to go back to previous screen.

The Ack and control power interruption event icon disappears only
when you press Yes.
NOTE: You can reset the Number of Losses to 0 only through the
Modbus communication. To perform this reset, you need to disable the 4-
digit MID/Revenue Lock password in the meter HMI.

Wrench icon
The wrench icon appears on the top left corner of the display screen.

The wrench icon alerts you when there is an overvoltage condition or a

potential hardware or firmware problem in the meter that requires attention. It
could also indicate that the energy pulsing LED is in an overrun state.
Navigate to Maint > Diag > Meter to view details of the meter status. Make note of
the information shown on the screen, then contact Technical Support.

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LED indicators
Abnormal heartbeat / serial communications LED behavior could mean potential
problems with the meter.

Problem Probable causes Possible solutions

LED flash rate does not Communications wiring If using a serial-to-RS-485
change when data is sent from converter, trace and check that
the host computer. all wiring from the computer to
the meter is properly
terminated.
Internal hardware problem Perform a hard reset: turn off
control power to the meter,
then re-apply power. If the
problem persists, contact
Technical Support.

Heartbeat / serial Internal hardware problem Perform a hard reset: turn off
communications LED remains control power to the meter,
lit and does not flash ON and then re-apply power. If the
OFF problem persists, contact
Technical Support.

Heartbeat / serial Display setup parameters Review display parameter

communications LED flashes, incorrectly set setup.
but the display is blank.

If the problem is not fixed after troubleshooting, contact Technical Support for
help. Make sure you have your meter’s firmware version, model and serial number
information available.

Phasors
Phasors are used to represent the voltage and current relative magnitude and
angles.
The length of the lines in the phasor diagram represent the relative magnitude of
the voltages with respect to the other phase voltages, and the currents with
respect to the other phase currents. All angles are measured with respect to the
Va/V1 phase. The Va/V1 phasor is fixed to the right-hand horizontal axis (positive
x-axis). Positive angles are measured counterclockwise.
Numeric values are provided for the magnitude and relative angle for each voltage
and current phase.
Phasor information can be used to troubleshoot incorrect connections on the
meter’s voltage and current inputs (for example, switched phase wiring or polarity
errors), if you know how the phasors should be oriented for your power system.

Phasor screens
Phasor information is available on the meter’s display.

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The graph on the Phasors screen shows a representation of the phase angles in
degrees. The Polar screen shows the RMS value and phase angle of each voltage
and current phases.
NOTE: If two phasor lines overlap (i.e. if they have the same relative phase
angle), only one phase label is visible as phasor diagram labels are
overwritten dynamically on the display panel.

Meter memory
The meter stores configuration and logging information in non-volatile memory
and a long-life memory chip.
The meter uses its non-volatile memory (NVRAM) to retain all data and metering
configuration values. Under the operating temperature range specified for the
meter, the NVRAM has an anticipated life of 45 years or longer. The meter stores
its data logs in a memory chip, which has a life expectancy of up to 20 years under
the operating temperature range specified for the meter.

Meter battery
The internal battery in the meter keeps the meter’s clock running when it is
powered down to help maintain the meter time.
The life expectancy of the meter’s internal battery is estimated to be over 10 years
at 25 °C under typical operating conditions.

Firmware version, model and serial number

You can view the meter model, serial number, date of manufacture, firmware
version (including OS - Operating System and RS - Reset System), language
version, and OS CRC (Cyclic Redundancy Check) from the display panel or
through the meter webpages.
• Using the display panel: Navigate to Maint > Diag > Info.
• Using the meter webpages: Based on your meter firmware version, click
Diagnostics > Meter Information OR click Home > Device Identification.
NOTE: The OS CRC value is a number that identifies the uniqueness between
different OS firmware versions.

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Firmware upgrades
Upgrade your meter’s firmware for the following reasons:
• Improve meter performance (e.g., optimize processing speed)
• Enhance existing meter features and functions
• Add new functionality to the meter
• Achieve compliance to new industry standards
• Enhance meter Cybersecurity
NOTE: Based on your meter model and firmware version, refer to the
appropriate sections of this chapter for the firmware upgrade procedure
as shown in table below:
Meter models, firmware versions and firmware upgrade methods

Meter models Source firmware Target firmware Firmware upgrade method via
version version
PM5560 / PM5562 / 2.X.Y 2.9.9 and earlier FTP server (Refer Firmware upgrade using FTP server, page 201)
PM5563 / PM5580
2.5.X to 2.9.9 4.0.X and above Firmware upgrade tool (Refer Firmware upgrade using firmware
upgrade tool, page 203)
NOTE: If the meters are upgraded to their target firmware
version, you cannot go back (downgrade) to their source
firmware version.
4.0.X and above 4.X.Y and above Webpages (Refer Firmware upgrade using webpages, page 205)

PM5570 / PM5660 / 3.1.X 3.2.9 and earlier FTP server (Refer Firmware upgrade using FTP server, page 201)
PM5760
3.2.9 and earlier 6.0.X and above Firmware upgrade tool (Refer Firmware upgrade using firmware
upgrade tool, page 203)
NOTE: If the meters are upgraded to their target firmware
version, you cannot go back (downgrade) to their source
firmware version.
6.0.X and above 6.X.Y and above Webpages (Refer Firmware upgrade using webpages, page 205)

PM5650 2.11.X 2.12.9 and FTP server (Refer Firmware upgrade using FTP server, page 201)
earlier
2.12.9 and earlier 4.10.X and Firmware upgrade tool (Refer Firmware upgrade using firmware
above upgrade tool, page 203)
NOTE: If the meters are upgraded to their target firmware
version, you cannot go back (downgrade) to their source
firmware version.
4.10.X and above 4.10.Y and Webpages (Refer Firmware upgrade using webpages, page 205)
above
PM5561 10.8.X 10.9.9 and FTP server (Refer Firmware upgrade using FTP server, page 201)
earlier
10.9.9 and earlier 12.0.X and Firmware upgrade tool (Refer Firmware upgrade using firmware
above upgrade tool, page 203)
NOTE: If the meters are upgraded to their target firmware
version, you cannot go back (downgrade) to their source
firmware version.
12.0.X and above 12.X.Y and Webpages (Refer Firmware upgrade using webpages, page 205)
above
PM5661 / PM5761 11.0.X 11.2.9 and earlier FTP server (Refer Firmware upgrade using FTP server, page 201)

11.2.9 and earlier 14.0.X and Firmware upgrade tool (Refer Firmware upgrade using firmware
above upgrade tool, page 203)
NOTE: If the meters are upgraded to their target firmware
version, you cannot go back (downgrade) to their source
firmware version.
14.0.X and above 14.X.Y and Webpages (Refer Firmware upgrade using webpages, page 205)
above

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Firmware upgrade methods

Meter upgrade requirements for FTP server

NOTE: To know the applicable firmware upgrade method for your meter model
with firmware version, refer to table Meter models, firmware versions and
firmware upgrade methods, page 200.
NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
There are some requirements to consider before you upgrade your meter’s
firmware.
In order to upgrade the meter, you need to:
• Be connected to the meter using Ethernet.
NOTE: It is recommended that you change the IP Address Acquisition
Mode to Stored during the firmware upgrade. If the mode is set to DCHP,
the IP address might change during the upgrade, which will result in a
loss of communications with the meter.
• Make sure the meter’s FTP server is enabled.
• Have Product Master credentials to login to the meter’s FTP server. The FTP
server uses the same user accounts as the meter’s webpages.
• Download the latest upgrade files from www.se.com. The upgrade files
include:
◦ App2.out: this file contains the files needed to upgrade the code and
initialization files that run the Ethernet communications.
◦ PM5xxx_vX.Y.Z.fwa (where xxx is your meter model and X.Y.Z is the
specific firmware version): this file contains all the files needed to upgrade
other meter components, such as the meter’s operating system, language
files and webpages.
◦ PM5500StartUpgrade.shtml
Save these files to a location you can access from the computer you use to
perform the upgrade.
NOTE: After you use the FTP meter upgrade process, you can no longer use
DLF3000 software to upgrade the meter.
NOTE: The PM5561 / PM5661 / PM5761 meter models running on firmware
version 10.6.3 or later, can be upgraded to a compatible higher firmware
version. However, firmware upgrades - successful and unsuccessful - are
limited to 10 attempts in PM5561 / PM5661 / PM5761, after which further
attempts will be blocked.

Firmware upgrade using FTP server

NOTE: To know the applicable firmware upgrade method for your meter model
with firmware version, refer to table Meter models, firmware versions and
firmware upgrade methods, page 200.
NOTE: Refer to Restoration of temporarily disabled configuration settings in
webpages, page 225 to know availability of these features on your meter
model.
You can upgrade the meter’s firmware, language files, webpages and Ethernet
communications card using the meter’s internal FTP server.
Your meter, Ethernet card and accessories do not operate normally during
firmware upgrade, and your meter’s digital outputs may change state during a
firmware upgrade.

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WARNING
UNINTENDED OPERATION OR METER DAMAGE
• Do not use this device for critical control or protection applications where
human or equipment safety relies on the operation of the control circuit.
• Do not turn off power to the meter while the firmware upgrade is in progress.
Failure to follow these instructions can result in death, serious injury, or
equipment damage.

This example walks through upgrading your meter using Windows Explorer to
access the meter’s FTP server. You can also use other FTP clients, such as
FileZilla.
1. Open Windows Explorer and connect to your meter by entering
ftp:\\<meter IP address> replacing <meter IP address> with the IP address of
the meter you want to upgrade.
2. Enter a Product Master Username and Password when prompted.
The FTP server appears, containing the folders fw and www.
3. Open another instance of Windows Explorer and navigate to the location
where you saved the firmware upgrade files.
4. Copy the PM5500StartUpgrade.shtml file and paste it into the www folder on
the meter’s FTP server.
5. Copy the App2.out and PM5xxx_vX.Y.Z.fwa files and paste them into the fw
folder on the meter’s FTP server.
NOTE: If a file with the same name already exists on the meter, you are
prompted to confirm whether or not you want to replace that file. Click Yes
(to replace that one file) or Yes to All (to replace all files).
NOTE: If you have added a large number of custom files (such as
webpages) to the meter’s FTP server, there may not be enough memory
on the meter’s Ethernet communications card to paste the files, and you
may receive an error when you try to paste the files. You may need to
temporarily move some of these custom files before proceeding.
6. Exit Windows Explorer after the file copying is complete.
7. Open your browser and enter http://<meter IP address>/
PM5500StartUpgrade.shtml to trigger the upgrade, where <meter IP
address> is replaced with your meter’s IP address.
Enter your login credentials when prompted.
NOTE: Accessing this webpage restarts the meter’s Ethernet
communications card, which initiates the upgrade process. It might take a
minute or two while the meter’s Ethernet communications card is reset
and the upgrade initialized.
From the PM5500StartUpgrade.shtml page, you are redirected to a firmware
upgrade status page where you can view information about the upgrade
process.

NOTE: If the status page indicates that one of the upgrade processes failed,
restart the upgrade process from the beginning by reconnecting to the meter’s
FTP server, recopying the files then following the rest of the procedure.

Meter upgrade requirements for firmware upgrade tool

NOTE: To know the applicable firmware upgrade method for your meter model
with firmware version, refer to table Meter models, firmware versions and
firmware upgrade methods, page 200.
Following pre-requisites are required for firmware upgrade:
• Latest compatible firmware upgrade package (Download the latest firmware
upgrade package from www.se.com).

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• Latest firmware upgrade tool which is included in firmware upgrade package.

• PC with Windows 10 and above operating system connected to meter via
Ethernet network.
• Uninterrupted power supply to the control power input of the meter, with
stable Ethernet communication.
• Meters configured with STATIC IP under Stored method.
• ION Setup configuration tool.

Firmware upgrade using firmware upgrade tool

NOTE: To know the applicable firmware upgrade method for your meter model
with firmware version, refer to table Meter models, firmware versions and
firmware upgrade methods, page 200.
NOTE: For this firmware upgrade method to be successful, do not change the
file names.

CAUTION
POTENTIAL FOR PRODUCT DAMAGE AND IRRECOVERABLE
Do not disrupt the auxiliary control power when the firmware upgrade is in
progress.
Failure to follow these instructions may result in product being damaged
and irrecoverable.

If the meter is connected to network and configured with STATIC IP address,

proceed to Step 2, page 203.
If the meter is connected to network and configured in DHCP mode:
• Disconnect the meter from the network.
• Switch the IP method to Stored.
• Connect the PC directly to the meter.
1. Configure the meter HTTP port number to 80 using the webpage (Settings >
Advanced Ethernet Settings) or through ION Setup.
2. Check that the IP domain of the PC is set to same as meter, and that the
meter is communicating with the PC (for example, by running a ping test).
3. Open the Config.csv file which is part of the firmware upgrade tool package.
4. Modify the Config.csv file in Notepad and enter the meter's configuration in
below order without the <> brackets and without any spaces around the
commas:
<IP Address>,<Modbus Slave ID>,<Web-master username>,<Web-master
password>,<Product-Master username>,<Product-Master password>
NOTE: Before saving the Config.csv file, ensure that the file
contains only one line text, and the last character of this line is the
Product-Master password without space, dot, comma etc.
Example: 192.168.0.10,255,user1,pass1,user2,pass2
5. Save and close the .csv file
6. Double click the PM5000fwupgrade.exe to open the firmware upgrade tool.

7. Select File > Open OR click the icon.

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8. Browse and select the updated Config.csv file. The tool displays the details
entered in config.csv file. Proceed to next step if the details mentioned as
follows match:
• IP Address (modified in the .csv file)
• Current firmware version of the meter
• Product name
• Status (Example: Firmware upgrade applicable)
NOTE: If the firmware upgrade tool displays status message other than
Firmware upgrade applicable, recheck the connection, meter, and the
details provided in config.csv file.

9. Select Tools > Select Firmware OR click the icon.

10. Click to browse and select the latest firmware file (.sedp).
Selected firmware file (VX.Y.Z.sedp) details will be displayed.

11. Select Tools > Upload Firmware OR click the icon.

12. A warning message displays. Make sure that you read and understand the
message. Select Yes to proceed or No to cancel upgrade process.
The firmware upgrade process starts. Depending on several factors like
network speed etc., the firmware upgrade process of the meter can take
about 5 minutes or more.
After the firmware upgrade process is completed, the status message
displays Device upgrade success.
13. Login to the webpage with the user credentials to find the latest upgraded
firmware version in the Home tab under the Device Identification window.
14. If the error message Device upgrade failed is displayed during the firmware
upgrade process:
a. Delete the downloaded copy of the latest firmware upgrade package
from the PC. Download the package from www.se.com again and retry
the firmware upgrade process. If the same issue occurs, contact
Schneider Electric Technical Support.
15. If the firmware upgrade process is interrupted or becomes unresponsive
(more than 5 minutes have elapsed since beginning the upgrade process and
the meter has not finished the upgrade attempt):
a. Remove the auxiliary control power to the meter and restore it after 10 s.
If the meter powers up normally and is able to establish Ethernet
communication, retry the firmware upgrade process.
If the firmware upgrade process is unsuccessful or if the meter does not
power up normally or if the Ethernet communication is not established
with the meter, contact Schneider Electric Technical Support.

Meter upgrade requirements for webpages

NOTE: To know the applicable firmware upgrade method for your meter model
with firmware version, refer to table Meter models, firmware versions and
firmware upgrade methods, page 200.
Following pre-requisites are required for firmware upgrade:
• Latest compatible firmware upgrade package (Download the latest firmware
upgrade package from www.se.com).
• PC with Windows 10 and above operating system connected to meter via
Ethernet network.
• Uninterrupted power supply to the control power input of the meter, with
stable Ethernet communication.

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Firmware upgrade using webpages

NOTE: To know the applicable firmware upgrade method for your meter model
with firmware version, refer to table Meter models, firmware versions and
firmware upgrade methods, page 200.

CAUTION
POTENTIAL FOR PRODUCT DAMAGE AND IRRECOVERABLE
Do not disrupt the auxiliary control power when the firmware upgrade is in
progress.
Failure to follow these instructions may result in product being damaged
and irrecoverable.

NOTE: Meter firmware includes a digital signature which helps ensure

authenticity.
1. Click Maintenance > Upgrade > Firmware.
2. In the Firmware Upgrade section, click Browse button.
The Choose File Open dialog box opens.
3. Select the .sedp file from the firmware release folder.
4. Click Upgrade button.
The pop-up message Do you want to apply the firmware upgrade now?
The product will be restarted and all users will be disconnected from the
application opens.
5. Click Yes to apply the firmware upgrade.
NOTE: The device will check the firmware compatibility before upgrade.
Depending on several factors like network speed etc., the firmware upgrade
process of the meter can take about 5 minutes or more.
After successful firmware upgrade, the meter can take up to 40 s to resume
communication.
6. After the firmware upgrade process, navigate to Maintenance > Upgrade >
Upgrade Status to check the last firmware upgrade status of your meter.
7. If the error message The firmware upgrade failed. The selected firmware
is either invalid or corrupted. is displayed during the firmware upgrade
process:
a. Click the Close button on the pop-up message.
b. Delete the downloaded copy of the latest firmware upgrade package
from the PC. Download the package from www.se.com again and retry
the firmware upgrade process. If the same issue occurs, contact
Schneider Electric Technical Support.
8. If the firmware upgrade process is interrupted or becomes unresponsive
(more than 5 minutes have elapsed since beginning the upgrade process and
the meter has not finished the upgrade attempt):
a. Remove the auxiliary control power to the meter and restore it after 10 s.
If the meter powers up normally and is able to establish Ethernet
communication, retry the firmware upgrade process.
If the firmware upgrade process is unsuccessful or if the meter does not
power up normally or if the Ethernet communication is not established
with the meter, contact Schneider Electric Technical Support.

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Technical assistance
Visit www.se.com for support and assistance with lost passcodes or other
technical problems with the meter.
Make sure you include your meter’s model, serial number and firmware version in
your email or have it readily available if calling Technical Support.

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Verifying accuracy
Overview of meter accuracy
All meters are tested and verified at the factory in accordance with International
Electrotechnical Commission (IEC) and American National Standards Institute
(ANSI) standards.
Your digital power meter typically does not require re-calibration. However, in
some installations a final accuracy verification of the meters is required, especially
if the meters will be used for revenue or billing applications.
For a list of accuracy standards that your meter complies to, contact your local
Schneider Electric representative or download the meter brochure from
www.se.com.

Accuracy test requirements

The most common method for testing meter accuracy is to apply test voltages and
currents from a stable power source and compare the meter’s readings with
readings from a reference device or energy standard.

Signal and power source

The meter maintains its accuracy during voltage and current signal source
variations but its energy pulsing output needs a stable test signal to help produce
accurate test pulses. The meter’s energy pulsing mechanism needs
approximately 10 seconds to stabilize after every source adjustment.
The meter must be connected to control power in order to conduct accuracy
verification testing. Refer to your meter’s installation documentation for power
supply specifications.

DANGER
HAZARD OF ELECTRIC SHOCK, EXPLOSION, OR ARC FLASH
Verify the device’s power source meets the specifications for your device’s
power supply.
Failure to follow these instructions will result in death or serious injury.

Control equipment
Control equipment is required for counting and timing the pulse outputs from an
energy pulsing LED or digital output.
• Most standard test benches have an arm equipped with optical sensors to
detect LED pulses (the photodiode circuitry converts detected light into a
voltage signal).
• The reference device or energy standard typically has digital inputs that can
detect and count pulses coming from an external source (i.e., the meter’s
digital output).
NOTE: The optical sensors on the test bench can be disrupted by strong
sources of ambient light (such as camera flashes, florescent tubes, sunlight
reflections, floodlights, etc.). This can cause test errors. Use a hood, if
necessary, to block out ambient light.

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Environment
The meter should be tested at the same temperature as the testing equipment.
The ideal temperature is about 23 ºC (73 ºF).
A warm-up time of 30 minutes is recommended before beginning energy accuracy
verification testing. At the factory, the meters are warmed up to their typical
operating temperature before calibration to help ensure that the meters will reach
their optimal accuracy at operating temperature.
Most high precision electronic equipment requires a warm up time before it
reaches its specified performance levels.

Reference device or energy standard

To help ensure the accuracy of the test, it is recommended that you use a
reference device or reference energy standard with a specified accuracy that is 6
to 10 times more accurate than the meter under test. Before you start testing, the
reference device or energy standard should be warmed up as recommended by
the manufacturer.
NOTE: Verify the accuracy and precision of all measurement equipment used
in accuracy testing (for example, voltmeters, ammeters, power factor meters).

Energy pulsing
You can configure the meter’s alarm /energy LED or the digital output(s) for
energy pulsing.
• The meter is equipped with an alarm / energy pulsing LED. When configured
for energy pulsing, the LED emits pulses that are then used to determine the
accuracy of the meter’s energy measurements.
• The meter sends the pulses from the configured digital output(s) port, which
are then used to determine the accuracy of the meter’s energy
measurements by pulse counter.

Meter settings for accuracy testing

Your meter‘s power system and other parameters must be configured for accuracy
testing.

Meter parameter Value

Power system 3PH4W Wye Gnd (3-phase, 4 wire Wye with

ground)

Energy pulse constant In sync with reference test equipment

(alarm/energy pulsing LED or digital output)

Verifying accuracy test

The following tests are guidelines for accuracy testing your meter; your meter
shop may have specific testing methods.

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DANGER
HAZARD OF ELECTRIC SHOCK, EXPLOSION, OR ARC FLASH
• Apply appropriate Personal Protective Equipment (PPE) and follow safe
electrical work practices. See NFPA 70E, CSA Z462 or other local
standards.
• Turn off all power supplying this device and the equipment in which it is
installed before working on or in the equipment.
• Always use a properly rated voltage sensing device to confirm that all power
is off.
• Do not exceed the maximum ratings of this device.
• Verify the device’s power source meets the specifications for your device’s
power supply.
Failure to follow these instructions will result in death or serious injury.

1. Turn off all power supplying this device and the equipment in which it is
installed before working on the device or equipment.
2. Use a properly rated voltage sensing device to confirm that all power is off.
3. Connect the test voltage and current source to the reference device or energy
standard. Ensure all voltage inputs to the meter under test are connected in
parallel and all current inputs are connected in series.

A Reference device or energy standard

B Test voltage and current source

C Meter under test

4. Connect the control equipment used for counting the standard output pulses
using one of these methods:

Option Description

Energy pulsing LED Align the red light sensor on the standard test bench armature over
the energy pulsing LED.

Digital output Connect the meter’s digital output to the standard test bench pulse
counting connections.

NOTE: When selecting which method to use, be aware that energy

pulsing LEDs and digital output(s) have different pulse rate limits.
5. Before performing the verification test, let the test equipment power up the
meter and apply voltage for at least 30 seconds. This helps stabilize the
internal circuitry of the meter.
6. Configure the meter’s parameters for verifying accuracy testing.

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7. Depending on the method selected for counting the energy pulses, configure
the meter’s energy pulsing LED or one of the digital output(s) to perform
energy pulsing. Set the meter’s energy pulse constant so it is in sync with the
reference test equipment.
8. Perform accuracy verification on the test points. Run each test point for at
least 30 seconds to allow the test bench equipment to read an adequate
number of pulses. Allow 10 seconds of dwell time between test points.

Required pulses calculation for accuracy verification testing

Accuracy verification test equipment typically requires you to specify the number
of pulses for a specific test duration.
The reference test equipment typically requires you to specify the number of
pulses required for a test duration of “t” seconds. Normally, the number of pulses
required is at least 25 pulses, and the test duration is greater than 30 seconds.
Use the following formula to calculate the required number of pulses:
Number of pulses = Ptot x K x t/3600
Where:
• Ptot = total instantaneous power in kilowatts (kW)
• K = the meter’s pulse constant setting, in pulses per kWh
• t = test duration, in seconds (typically greater than 30 seconds)

Total power calculation for accuracy verification testing

Accuracy verification testing supplies the same test signal (total power) to both the
energy reference/standard and the meter under test.
Total power is calculated as follows, where:
• Ptot = total instantaneous power in kilowatts (kW)
• VLN = test point line-to-neutral voltage in volts (V)
• I = test point current in amps (A)
• PF = power factor
The result of the calculation is rounded up to the nearest integer.
For a balanced 3–phase Wye system:
Ptot = 3 x VLN x I x PF x 1 kW/1000 W
NOTE: A balanced 3–phase system assumes that the voltage, current and
power factor values are the same for all phases.
For a single-phase system:
Ptot = VLN x I x PF x 1 kW/1000W

Percentage error calculation for accuracy verification testing

Accuracy verification testing requires you to calculate the percentage error
between the meter being tested and the reference/standard.
Calculate the percentage error for every test point using the following formula:
Energy error = (EM - ES) / ES x 100%
Where:
• EM = energy measured by the meter under test
• ES = energy measured by the reference device or energy standard.
NOTE: If accuracy verification reveals inaccuracies in your meter, they may be
caused by typical sources of test errors. If there are no sources of test errors
present, please contact your local Schneider Electric representative.

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Accuracy verification test points

The meter should be tested at full and light loads and at lagging (inductive) power
factors to help ensure testing over the entire range of the meter.
The test amperage and voltage input rating are labeled on the meter. Refer to the
installation sheet or data sheet for your meter’s nominal current, voltage and
frequency specifications.

Watt-hour test point Sample accuracy verification test point

Full load 100% to 200% of the nominal current, 100% of the nominal voltage and
nominal frequency at unity power factor or one (1).

Light load 10% of the nominal current, 100% of the nominal voltage and nominal
frequency at unity power factor or one (1).

Inductive load (lagging 100% of the nominal current, 100% of the nominal voltage and nominal
power factor) frequency at 0.50 lagging power factor (current lagging voltage by 60°
phase angle).

VAR-hour test point Sample accuracy verification test point

Full load 100% to 200% of the nominal current, 100% of the nominal voltage and
nominal frequency at zero power factor (current lagging voltage by 90°
phase angle).

Light load 10% of the nominal current, 100% of the nominal voltage and nominal
frequency at zero power factor (current lagging voltage by 90° phase
angle).

Inductive load (lagging 100% of the nominal current, 100% of the nominal voltage and nominal
power factor) frequency at 0.87 lagging power factor (current lagging voltage by 30°
phase angle).

Energy pulsing considerations

The meter’s energy pulsing LED and pulse outputs are capable of energy pulsing
within specific limits.

Description Energy pulsing LED Pulse output

Maximum pulse frequency 2.5 kHz 25 Hz

Minimum pulse constant 1 pulse per k_h

Maximum pulse constant 9,999,000 pulses per k_h

The pulse rate depends on the voltage, current and PF of the input signal source,
the number of phases, and the VT and CT ratios.
If Ptot is the instantaneous power (in kW) and K is the pulse constant (in pulses
per kWh), then the pulse period is:
3600 1
Pulse period (in seconds) = =
K x Ptot Pulse frequency (Hz)

VT and CT considerations
Total power (Ptot) is derived from the values of the voltage and current inputs at
the secondary side, and takes into account the VT and CT ratios.
The test points are always taken at the secondary side, regardless of whether VTs
or CTs are used.
If VTs and CTs are used, you must include their primary and secondary ratings in
the equation. For example, in a balanced 3-phase Wye system with VTs and CTs:

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VTp CTp 1 kW
Ptot = 3 x VLN x xIx x PF x
VTs CTs 1000 W
where Ptot = total power, VTp = VT primary, VTs = VT secondary, CTp = CT
primary, CTs = CT secondary and PF = power factor.

Example calculations
This example calculation shows how to calculate power, pulse constants and
maximum pulse frequency, and how to determine a pulse constant that reduces
the maximum pulse frequency.
A balanced 3-phase Wye system uses 480:120 volt VTs and 100:5 amp CTs. The
signals at the secondary side are 119 volts line-to-neutral and 4.99 amps, with a
power factor of 0.85. The desired pulse output frequency is 20 Hz (20 pulses per
second).
1. Calculate the typical total output power (Ptot):

Ptot = 3 x 119 x 480 x 4.99 x 100 x 0.85 x 1 kW = 141.14 kW

120 5 1000 W

2. Calculate the pulse constant (K):

K= 3600 x (pulse frequency) = 3600 seconds/hour x 20 pulses/second

Ptot 121.14 kW

K= 594.4 pulses / kWh

3. At full load (200% of nominal current = 10 A) and power factor (PF = 1),
calculate the maximum total output power (Pmax):

Pmax = 3 x 119 x 480 x 10 x 100 x 1 x 1 kW = 285.6 kW

120 5 1000 W
4. Calculate the maximum output pulse frequency at Pmax:

Maximum pulse frequency = K x Pmax = 594.4 pulses / kWh x 285.6 kW

3600 3600 seconds/hour
Maximum pulse frequency = 47.2 pulses/second = 47.2 Hz
5. Check the maximum pulse frequency against the limits for the LED and digital
outputs:
• 47.2 Hz ≤ LED maximum pulse frequency (2.5 kHz)
• 47.2 Hz > digital output maximum pulse frequency (25 Hz)
NOTE: The maximum pulse frequency is within the limits for LED energy
pulsing. However, the maximum pulse frequency is greater than the limits
for digital output energy pulsing. Pulse output frequencies greater than 25
Hz will saturate the digital output and cause it to stop pulsing. Therefore in
this example, you can only use the LED for energy pulsing.

Adjustments to allow energy pulsing at the digital outputs

If you want to use the digital output, you must reduce the output pulse frequency
so it is within the limits.
Using the values from the above example, the maximum pulse constant for the
digital output is:

Kmax = 3600 x (digital output maximum pulse frequency) = 3600 x 2.5

Pmax 285.6
Kmax = 315.13 pulses per kWh

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1. Set the pulse constant (K) to a value below Kmax, for example, 300 pulses/
kWh. Calculate the new maximum output pulse frequency at Pmax:

New maximum pulse frequency = K x Pmax = 300 pulses/kWh x 285.6 kW

3600 3600 seconds/hour
New maximum pulse frequency = 23.8 pulses/second = 23.8 Hz
2. Check the new maximum pulse frequency against the limits for the LED and
digital outputs:
• 23.8 Hz ≤ LED maximum pulse frequency (2.5 kHz)
• 23.8 Hz ≤ digital output maximum frequency (25 Hz)
As expected, changing K to a value below Kmax allows you to use the digital
output for energy pulsing.
3. Set the new pulse constant (K) on your meter.

Typical sources of test errors

If you see excessive errors during accuracy testing, examine your test setup and
test procedures to eliminate typical sources of measurement errors.
Typical sources of accuracy verification testing errors include:
• Loose connections of voltage or current circuits, often caused by worn-out
contacts or terminals. Inspect terminals of test equipment, cables, test
harness and the meter under test.
• Meter ambient temperature is significantly different than 23 °C (73 °F).
• Floating (ungrounded) neutral voltage terminal in any configuration with
unbalanced phase voltages.
• Inadequate meter control power, resulting in the meter resetting during the
test procedure.
• Ambient light interference or sensitivity issues with the optical sensor.
• Unstable power source causing energy pulsing fluctuations.
• Incorrect test setup: not all phases connected to the reference device or the
energy standard. All phases connected to the meter under test should also be
connected to the reference meter/standard.
• Moisture (condensing humidity), debris or pollution present in the meter under
test.

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PowerLogic™ PM5500 / PM5600 / PM5700 series Revenue

Revenue
Revenue metering overview
A revenue meter provides, over a defined range of operating conditions,
measurements that are within international and national defined standards and
industry-accepted accuracy limits.
It also provides protection against unauthorized alteration of these measured
quantities. National and utility-based standards regulate protection against
unauthorized alteration of measured quantities.

Revenue metering components

To meet government regulations and utility security requirements, the meter
incorporates three types of security systems:
• Traditional anti-tamper mechanical seals on the meter
• Passcode entry to reset meter values, for example, Master reset.
• Hardware locking mechanism that prevents modification of revenue quantities
after they are locked.

Revenue firmware security features

Your revenue-specific meter has additional firmware security features.
You cannot perform resets or configure some revenue-specific parameters on
your meter while it is revenue-locked.

Revenue meters and firmware upgrades

Meter model Upgrade information

PM5561 / PM5661 / PM5761 The OS CRC value is a number that identifies the uniqueness between different OS firmware versions.

PM5562 / PM5562MC You cannot upgrade a locked meter.

In order to upgrade, you must:

• Remove the meter from service and unseal it.
• Follow the unlocking / locking procedure to unlock the meter.
• Perform the upgrade.
• Follow the unlocking / locking procedure to lock the meter.
• Re-seal and re-certify your meter with the appropriate revenue metering authorities.

NOTICE
LOSS OF COMPLIANCE
Ensure that you re-certify your meter with the appropriate revenue metering
authorities after re-enabling the hardware-based security.
Failure to follow these instructions may render your device non-compliant
for billing purposes.

Protected setup parameters and functions

Your meter has features and settings that cannot be changed while the meter is
revenue-locked.

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In order to prevent modifications to revenue-related settings and data on your

meter, some of the features and parameters on your meter cannot be edited once
the meter is revenue-locked.

Protected setup parameters

Settings Protected status Description

Power system settings 8 Yes You cannot change any power system settings while the meter is
locked (for example, power system type, VT and CT connections,
VT and CT primary and secondary values, system frequency and
phase rotation)

Meter label Yes You cannot change the meter label while the meter is locked

Meter date Yes You cannot change the meter’s date while the meter is locked

Energy pulsing PM5561 / PM5661 / The alarm / energy pulsing LED on the PM5561 / PM5661 /
PM5761: See description PM5761 is permanently set for energy pulsing and cannot be
disabled or used for alarms. All other setup parameters for the
PM5562 /PM5562MC: energy pulsing LED are also permanently set and cannot be
Not locked modified. The settings are fixed at:
• Mode (Control) = Energy (energy pulsing)
• Pulses per k_h (Pulse Rate) = 10,000 (pulses per kWh)
NOTE: The pulses per kWh reflect uncompensated
values only. This means that the PT and CT values are
ignored and the pulses represent the raw energy
calculated from the metering inputs.
• Channel (Parameter) = Active Energy Del+Rec

Multi-tariff and input metering settings Yes You cannot change multi-tariff mode or settings while the meter is
locked.

PM5561 / PM5661 / PM5761: You can only configure a subset of

input metering settings when the meter is locked (channel label and
demand code cannot be configured).

PM5562 /PM5562MC: You cannot configure input metering settings

when the meter is locked.
Energy reset passcode Yes You cannot change the energy reset passcode while the meter is
locked
Data Log 1 PM5561 / PM5661 / You cannot configure Data Log 1 on thePM5562 /PM5562MC when
PM5761: Not locked the meter is locked.

PM5562 /PM5562MC:
Yes

Protected functions
Meter Functions Description

PM5561 / PM5661 / PM5761 Resets After the meter is locked, the following resets are disabled:
• Global resets: Meter Initialization (all) and Energies
• Single resets: Energy and Multi-Tariff

Control power (auxiliary power) After the meter is locked, the control power (auxiliary power)
interruption event interruption event is acknowledged only after entering the 4-digit
MID/Revenue Lock password.

PM5562 / PM5562MC Resets After the meter is locked, the following resets are disabled:
• Global resets: Meter Initialization (all), Energies and Input
metering
• Single resets: All energy, multi-tariff and input metering resets

For a complete list of protected functions and settings, see your meter’s Modbus
register list, available from www.se.com.

8. For compliance, the Power System on the PM5561 / PM5562 / PM5562MC / PM5661 / PM5761 must be set to either 3PH4W Wye Gnd
(three-phase 4-wire wye grounded) or 3PH3W Dlt Ungnd (three-phase 3-wire delta ungrounded).

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Revenue-locking summary
You must configure and revenue lock your meter before installing it.
• Unlock your revenue meter if it is locked.
• Configure the required revenue settings specific for installation.
NOTE: If you are using ION Setup to configure your meter, allow for any
communication delays before removing power to your meter.
• Verify the revenue settings have been implemented.
• Clear all accumulated meter data.
• Revenue lock your meter.
• Verify the meter is revenue-locked.
• Install the meter and install the terminal covers according to your meter’s
installation sheet.

Revenue locking
Revenue locking your meter helps prevent modifications to revenue-related
settings and data on your meter, or tampering with your meter’s voltage and
current connections.
Revenue locking may be required to help meet government regulations and utility
security requirements, or can be used to help ensure the validity of revenue data.
You must configure all the lock-protected setup parameters before locking the
meter.

Locking or unlocking the PM5561 / PM5661 / PM5761

After you initialize the meter, you must lock it in order to conform to MID
standards.
Before you lock your meter:
• Make sure you have completed all necessary configuration.
• Perform a meter initialization reset to clear any previously accumulated meter
data.
A lost lock passcode cannot be recovered.

NOTICE
PERMANENTLY LOCKED DEVICE
Record your device's user and passcode information in a secure location.
Failure to follow these instructions can result in data loss.

1. Navigate to Maint > Lock.

2. Set Security Lock by entering a non-zero passcode (a number between 1
and 9999).
3. Select Yes to confirm locking the meter, then exit the screen.
A lock icon appears on the upper left corner of the screen.
4. Make sure you record and store the lock passcode in a secure location.
NOTE: To change the lock passcode, unlock the meter then lock it again
using a different passcode. Make sure you record this new passcode and
store it in a secure place.

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Revenue lock switch

The revenue lock switch is used to lock the PM5562 / PM5562MC meters.
The revenue lock switch located on top of the meter base and has a hole through
which you can install an anti-tamper seal after you lock your meter.

A Revenue lock status LED

B Revenue lock switch
C Sealing hole
Wire diameter: ≤ 2 mm (0.07 in)

Wire bend radius: ≤ 14 mm (0.55 in)

Locking and unlocking your meter using the hardware switch

You must lock PM5562 / PM5562MC meters using the hardware switch in order to
comply with certain revenue standards.
Before you lock your meter:
• Make sure you have completed all necessary configuration.
• Perform a meter initialization reset to clear any previously accumulated meter
data.

DANGER
HAZARD OF ELECTRIC SHOCK, EXPLOSION, OR ARC FLASH
• Apply appropriate Personal Protective Equipment (PPE) and follow safe
electrical work practices. See NFPA 70E, CSA Z462 or other local
standards.
• Turn off all power supplying this device and the equipment in which it is
installed before working on or in the equipment.
• Always use a properly rated voltage sensing device to confirm that all power
is off.
• Do not exceed the maximum ratings of this device.
• Verify the device’s power source meets the specifications for your device’s
power supply.
• Use a non-conductive or insulated seal.
Failure to follow these instructions will result in death or serious injury.

1. Turn off all power supplying this device and the equipment in which it is
installed before working on the device or equipment.
2. Use a properly rated voltage sensing device to confirm that all power is off.
3. Uninstall the meter if it is currently installed.
4. Locate the revenue lock switch.
5. Remove any anti-tamper seals from the revenue switch.
6. Place the meter base on a non-skid surface and make sure the meter is
secure during the lock / unlock process.
7. Apply control power to the meter.
8. Press and hold the switch for 10 seconds to toggle revenue locking on and
off.
9. Confirm the revenue lock status using the revenue lock icon on the display.

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10. Remove control power from the meter.

11. Thread your seal through the hole on the revenue lock switch, if required, and
seal.
Make sure you do not over-tighten the seal

12. Follow the instructions in the installation sheet to Install the meter and apply
the anti-tamper voltage and current terminal covers.

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Device specifications
The specifications contained in this section are subject to change without notice.
For installation and wiring information, refer to the meter installation sheet.

Mechanical characteristics
Applicable for all meter models except PM5563

IP degree of protection (IEC 60529) Display: IP54 (Upgrade to IP65 with optional accessory kit METSEIP65OP96X96FF)

Meter body: IP30 (except connectors)

Connectors: IP20 with terminal covers installed, IP10 without terminal covers

Enclosure rating Display: UL Type 12

For UL Type 12 applications, install meter and remote display on a flat surface of a Type 12
enclosure
Mounting position Vertical

Display type Monochrome graphics LCD, 128 x 128 resolution

Display backlight White LED

Viewable area 67 x 62.5 mm (2.64 x 2.46 in)

Applicable only for PM5563 meter model

IP degree of protection (IEC 60529) Meter body: IP30 (except connectors)

Connectors: IP20 with terminal covers installed, IP10 without terminal covers

Mounting position 35 mm DIN rail

Electrical characteristics
Measurement accuracy

• Measurement type: True RMS up to the 63rd harmonic on three-phase (3P, 3P + N); 128 samples per cycle, zero blind
• IEC 61557-12: PMD/[SD|SS]/K70/0.2

Measurement type Class of accuracy as per IEC 61557-12 Error

Active energy Class 0.2S (Class 0.2S as per IEC 62053-22 at 5 A Inominal (for 1 A Inominal when I > ±0.2%
0.15 A))

Reactive energy Class 2 (Class 2 as per IEC 62053-23 at 5 A Inominal (for 1 A Inominal when I > 0.15 ±2%
A))

Apparent energy Class 0.5 ±0.5%

Active power Class 0.2 ±0.2%

Reactive power Class 1 ±1%

Apparent power Class 0.5 ±0.5%

Current Class 0.2 ±0.15%

Voltage (L-N) Class 0.1 ±0.1%

Frequency Class 0.05 ±0.05%

Power factor Class 1 ±0.005 Count

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Power quality accuracy

Measurement type Class of accuracy as per IEC 61557-12 Error

Voltage unbalance Class 2 ±2%

Voltage harmonics Class 2 ±2%

Voltage THD Class 2 ±2%

Current harmonics Class 2 ±2%

Current THD Class 2 ±2%

Voltage inputs

Maximum VT/PT primary 1.0 MV AC

Specified accuracy range 20 – 400 V L-N / 20 – 690 V L-L (Wye) or 20 – 600 V L-L (Delta)

UL Listed up to 347 V L-N / 600 V L-L

Measurement category CAT III (6 kV rated impulse voltage)

Overload 480 V L-N / 828 V L-L

Impedance 5 MΩ

Specified accuracy frequency 50 or 60 Hz ±10% (45 – 70 Hz)

Burden < 0.2 VA at 240 V AC L-N

Current inputs

Maximum CT primary 32767 A

CT secondary Nominal: 5 A (Class 0.2S) or 1 A (Class 0.5S)

Measured current with over range and 50 mA – 10 A

crest factor
Starting current 5 mA

Withstand 20 A continuous

50 A at 10 sec/hr

500 A at 1 sec/hr
Impedance 0.3 mΩ

Frequency 50 or 60 Hz ±10% (45 – 70 Hz)

Burden < 0.024 VA at 10 A

RCM inputs (Applicable for PM5660 / PM5661 / PM5760 / PM5761 meter models)

Type A (as per IEC 62020 Clause 9.19.2)

Frequency 45 – 65 Hz

Measurement range (meter) 5 μA to 1200 μA (nominal), 1500 μA max (continuous)

Burden 150 Ω

Default toroid turns 1000

AC control power (Applicable for PM5560 / PM5561 / PM5562 / PM5562MC / PM5563 / PM5650 meter
models)

Operating range 100 – 480 V AC ± 10%

Installation category CAT III 600V class per IEC 61010-1 edition 3

Burden 5.0 W / 16.0 VA / 15.2 VAR max at 480 V AC

Frequency 50 or 60 Hz ±10%

Ride-through time 35 ms typical at 120 V L-N and maximum burden

129 ms typical at 230 V L-N and maximum burden

220 HRB1684301-12
Device specifications PowerLogic™ PM5500 / PM5600 / PM5700 series

AC control power (Applicable for PM5570 / PM5660 / PM5661 / PM5760 / PM5761 meter models)

Operating range 100 – 480 V AC ± 10%

Installation category CAT III 600V class per IEC 61010-1 edition 3

Burden Maximum 13.1 VA / 4 W, Typical 10.6 VA at 230 V L-N

Frequency 50 or 60 Hz ±10%

Ride-through time 35 ms typical at 120 V L-N and maximum burden

129 ms typical at 230 V L-N and maximum burden

DC control power

Operating range 125 – 250 V DC ±20%

Burden Maximum 5 W, Typical 3.1 W at 125 V DC (Applicable for PM5560 / PM5561 / PM5562 /
PM5562MC / PM5563 / PM5650 meter models)

Maximum 4 W, Typical 3.6 W at 125 V DC (Applicable for PM5570 / PM5660 / PM5661 /

PM5760 / PM5761 meter models)

Ride-through time 50 ms typical at 125 V DC and maximum burden

Low-voltage DC control power (Applicable only for PM5580 meter model)

Operating range 20 – 60 V DC ±10%

Burden 4.1 W maximum

Ride-through time 15 ms typical at 18 – 60 V DC and maximum burden

Digital outputs

Number 2
Type Form A solid-state digital outputs

Maximum load voltage 40 V AC / 60 V DC (Applicable for PM5500 series and PM5650 meter model)

30 V AC / 40 V DC (Applicable for PM5660 / PM5661 / PM5760 / PM5761 meter models)

Maximum load current 125 mA

ON resistance 8Ω
Pulse frequency 25 Hz maximum

Pulse weight 1 to 9999999 pulses per k_h

Pulse width 50% duty cycle (20 ms minimum ON time)

Leakage current 1 µA

Isolation 2.5 kV RMS for 60 seconds

Digital inputs (Applicable for PM5650 meter model and PM5500 series except PM5570)

Number 4
Type Externally excited

Voltage OFF 0 – 6 V AC / 0 – 6 V DC

Voltage ON 15 – 30 V AC / 15 – 60 V DC

Input resistance 100 kΩ

Frequency 25 Hz maximum

Isolation 2.5 kV RMS for 60 seconds

Pulse width 50% duty cycle (20 ms minimum ON time)

HRB1684301-12 221
PowerLogic™ PM5500 / PM5600 / PM5700 series Device specifications

Digital inputs (Applicable for PM5650 meter model and PM5500 series except PM5570) (Continued)

Response time 10 ms

Input burden 2 mA at 24 V AC/DC

2.5 mA at 60 V AC/DC

Digital inputs (Applicable for PM5570 / PM5660 / PM5661 / PM5760 / PM5761 meter models)

Number 2
Type Externally excited

Voltage OFF 0 – 6 V AC / 0 – 6 V DC

Voltage ON 18 – 30 V AC / 12 – 40 V DC

Input resistance 100 kΩ

Frequency 25 Hz maximum

Isolation 2.5 kV RMS for 60 seconds

Pulse width 50% duty cycle (20 ms minimum ON time)

Response time 10 ms

Input burden 2 mA at 24 V AC/DC

2.5 mA at 60 V AC/DC

Analog inputs (Applicable only for PM5570 meter model)

Number 2
Type DC current

Range 4 – 20 mA

Accuracy ± 1% of full scale (0.2 mA)

Impedance < 20 Ω

Operating voltage 24 V DC maximum

Environmental characteristics
Operating temperature Meter: -25 to 70 °C (-13 to 158 °F)

Display: -20 to 70 °C (-4 to 158 °F)

Display functions to -25 ºC (-13 °F) with reduced performance

Storage temperature -40 to 85 °C (-40 to 185 °F)

Humidity rating Operating: 5% to 95% RH non-condensing

Storage: 5% to 80% RH non-condensing

Maximum dewpoint 37 °C (99 °F)

Pollution degree 2

Altitude ≤ 3000 m (9843 ft) CAT III

Location / mounting For indoor use only

Must be permanently connected and fixed

Product life > 15 years

222 HRB1684301-12
Device specifications PowerLogic™ PM5500 / PM5600 / PM5700 series

LEDs
LED indicators

Heartbeat / communications activity Green LED (front panel on display or remote display, top on DIN model)

Alarm / energy pulsing LED Amber LED (front panel on display or remote display, top on DIN model)

Revenue lock status Green LED (top on PM5562 / PM5562MC)

Active alarm / energy pulsing LED

Type Amber LED, optical

Maximum pulse frequency 50 Hz

Pulse width 50% duty cycle (200 µs minimum ON time)

Pulse weight 1 to 9999999 pulses per k_h

Wavelength 590 to 635 nm

EMC (electromagnetic compatibility)

Harmonic current emissions IEC 61000-3-2
Flicker (voltage fluctuation) limits IEC 61000-3-3

Immunity to electrostatic discharge IEC 61000-4-2

Immunity to radiated fields IEC 61000-4-3

Immunity to fast transients IEC 61000-4-4

Immunity to surges IEC 61000-4-5

Immunity to conducted disturbances, IEC 61000-4-6

150kHz to 80MHz
Immunity to magnetic fields IEC 61000-4-8

Immunity to voltage dips and IEC 61000-4-11

interruptions

Immunity to damped oscillatory waves IEC 61000-4-12

Radiated and conducted emissions FCC part 15 Class B, EN55022 Class B

Safety
Europe LVD compliance (EN61010-1:2010)

U.S. and Canada cULus (UL61010-1:2012, CSA22.2 No.61010-1-12)

Protective class Protective class II

Double insulated for user accessible parts

MID compliance
Applicable for PM5561 / PM5661 / PM5761 meter models

Applicable MID standards and class

• EN 50470-1:2006 Class C
index
• EN 50470-3:2006 Class C
Type of measuring equipment Static watt-hour meter

HRB1684301-12 223
PowerLogic™ PM5500 / PM5600 / PM5700 series Device specifications

Intended use Indoor use only, permanently mounted in residential, commercial or light industrial applications,
where levels of vibration and shock are of low significance

Mechanical environment M1
Electromagnetic (EMC) environment E2

Applicable measurements Active energy metering only (kWh or MWh)

Voltage at voltage terminals

• 3-phase 4-wire Wye grounded: 3 x 57.7 (100) to 3 x 400 (690) V AC
• 3-phase 3-wire Delta ungrounded: 3 x 100 to 3 x 600 V L-L

Electrical network frequency 50 Hz

RS-485 communications
Number of ports 1

Maximum cable length 1219 m (4000 ft)

Maximum number of devices (unit Up to 32 devices on the same bus

loads)

Parity Even, Odd, None (1 stop bit for Odd or Even parity; 2 stop bits for None)

Baud rate 9600, 19200, 38400 baud

Protocol Modbus RTU, Modbus ASCII (7 or 8 bit), Jbus

Isolation 2.5 kV RMS, double insulated

Ethernet communications
Number of ports 2

Maximum cable length 100 m (328 ft), per TIA/EIA 568-5-A

Mode 10Base-T, 100Base-TX, Auto-MDIX

Protocol Modbus TCP, HTTP / HTTPS**, FTP / FTPS**, DHCP, BOOTP, BACnet/IP, EtherNet/IP, DNP3*

*Available in specific meter models. Refer to Features differentiation matrix for PM5500 / PM5600 / PM5700 series, page 20 for the
availability.

**Available only in latest firmware versions:

• PM5560 / PM5562 / PM5563 / PM5580 meter models: 4.0.0 and above
• PM5570 / PM5660 / PM5760 meter models: 6.0.0 and above
• PM5650 meter model: 4.10.0 and above
• PM5561 meter model: 12.0.0 and above
• PM5661 / PM5761 meter models: 14.0.0 and above

Real-time clock
Clock drift ~ 0.4 seconds per day (typical)

Battery backup time 3 years without control power (typical)

224 HRB1684301-12
Restoration of temporarily disabled configuration settings in
webpages PowerLogic™ PM5500 / PM5600 / PM5700 series

Restoration of temporarily disabled configuration

settings in webpages
For the meter models with firmware versions mentioned in column (B) of table, the
configuration settings and login requirements in the webpages have been limited
to meet updated cybersecurity best practices. With additional cybersecurity
measures incorporated into the product, the functionalities have now been
restored with the latest firmware versions mentioned in column (C) of table.
NOTE: If your meter is presently running on firmware version mentioned
in columns (A) or (B) of table, upgrade your meter to the latest released
version of firmware as mentioned in column (C) of table to enhance your
product’s cybersecurity and to use all the features of the webpages
(Refer to Firmware upgrades, page 200).
NOTE:
• For the meter models with the firmware versions mentioned in column (B)
of table, the HTTP service is accessible without user credentials.
• To access FTP service, navigate to Maint > Setup > Comm > Enet and
set the FTP parameter to Enabled using the meter’s display.

Meter models and firmware versions

Firmware version series

Meter models (A) (B) (C)

No webpage limitations Webpage limitations No webpage limitations

PM5560 2.7.7 and earlier

PM5563 Not applicable 2.7.8 to 2.9.9 4.0.0 and above

PM5580 2.7.7 and earlier

PM5562 2.5.4 and earlier Not applicable 4.0.0 and above*

PM5650 Not applicable 2.10.0 to 2.12.9 4.10.0 and above*

PM5570
PM5660 Not applicable 3.0.0 to 3.2.9 6.0.0 and above*
PM5760

PM5561 Not applicable 10.8.2 to 10.9.9 12.0.0 and above*

PM5661
Not applicable 11.0.0 to 11.2.9 14.0.0 and above*
PM5761
* Coming soon, check www.se.com for latest updates.

HRB1684301-12 225
PowerLogic™ PM5500 / PM5600 / PM5700 series China Standard Compliance

China Standard Compliance

This product complies with the following standard(s) in China:

PM5560 / PM5563
IEC 62053-22:2003 Electricity metering equipment (A.C.) - Particular requirements - Part 22: Static
meters for active energy (Classes 0,2 S and 0,5 S)

IEC 61557-12:2007 Electrical safety in low voltage distribution systems up to 1 000 V a.c. and 1 500
V d.c. - Equipment for testing, measuring or monitoring of protective measures - Part 12:
Performance measuring and monitoring devices

UL61010-1 ed.3 - Safety requirements for electrical equipment for measurement, control, and
laboratory use - Part 1: General requirements

GB/T 22264.7-2008 安装式数字显示电测量仪表 第7部分：多功能仪表的特殊要求

PM5561 / PM5562 / PM5650

IEC 62053-22:2003 Electricity metering equipment (A.C.) - Particular requirements - Part 22: Static
meters for active energy (Classes 0,2 S and 0,5 S)

IEC 61557-12:2007 Electrical safety in low voltage distribution systems up to 1 000 V a.c. and 1 500
V d.c. - Equipment for testing, measuring or monitoring of protective measures - Part 12:
Performance measuring and monitoring devices

UL61010-1 ed.3 - Safety requirements for electrical equipment for measurement, control, and
laboratory use - Part 1: General requirements

PM5570 / PM5580 / PM5660 / PM5760

IEC 61010-1:2010 Safety requirements for electrical equipment for measurement, control, and
laboratory use - Part 1: General requirements

PM5661 / PM5761
UL61010-1 ed.3 - Safety requirements for electrical equipment for measurement, control, and
laboratory use - Part 1: General requirements

226 HRB1684301-12
Schneider Electric
35 rue Joseph Monier
92500 Rueil Malmaison
France
+ 33 (0) 1 41 29 70 00
www.se.com

As standards, specifications, and design change from time to time,

please ask for confirmation of the information given in this publication.

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HRB1684301-12