user and installation manual im02601004e60 hz. delta-sigma over-sampling increased from 1024...

User and Installation Manual IM02601004E

Power Xpert PXM 4000/6000/8000 Effective November 2011

Copyright © 2011 by Eaton Corporation. All rights reserved.

Eaton, Power Xpert, PowerChain Management, Powerware, and X-Slot are regis-tered trademarks of Eaton Corporation or its subsidiaries and affiliates. Microsoft and Windows are registered trademarks of Microsoft Corporation. Modbus is a registered trademark of Schneider Electric.

EATON CORPORATION - CONFIDENTIAL AND PROPRIETARY NOTICE TO PERSONS RECEIVING THIS DOCUMENT AND/OR TECHNICAL INFORMATION

THIS DOCUMENT, INCLUDING THE DRAWING AND INFORMATION CONTAINED THEREON, IS CONFIDENTIAL AND IS THE EXCLUSIVE PROPERTY OF EATON CORPORATION, AND IS MERELY ON LOAN AND SUBJECT TO RECALL BY EATON AT ANY TIME. BY TAKING POSSESSION OF THIS DOCUMENT, THE RECIPIENT ACKNOWLEDGES AND AGREES THAT THIS DOCUMENT CANNOT BE USED IN ANY MANNER ADVERSE TO THE INTERESTS OF EATON, AND THAT NO PORTION OF THIS DOCUMENT MAY BE COPIED OR OTHERWISE REPRODUCED WITHOUT THE PRIOR WRITTEN CONSENT OF EATON. IN THE CASE OF CONFLICTING CONTRAC-TUAL PROVISIONS, THIS NOTICE SHALL GOVERN THE STATUS OF THIS DOCU-MENT.

DISCLAIMER OF WARRANTIES AND LIMITATION OF LIABILITY

The information, recommendations, descriptions and safety notations in this docu-ment are based on Eaton Electrical Inc. and/or Eaton Corporation’s (“Eaton”) experi-ence and judgment and may not cover all contingencies. If further information is required, an Eaton sales office should be consulted.

Sale of the product shown in this literature is subject to the terms and conditions outlined in appropriate Eaton selling policies or other contractual agreement between Eaton and the purchaser.

THERE ARE NO UNDERSTANDINGS, AGREEMENTS, WARRANTIES, EXPRESSED OR IMPLIED, INCLUDING WARRANTIES OF FITNESS FOR A PARTICULAR PURPOSE OR MERCHANTABILITY, OTHER THAN THOSE SPECIFICALLY SET OUT IN ANY EXISTING CONTRACT BETWEEN THE PARTIES. ANY SUCH CONTRACT STATES THE ENTIRE OBLIGATION OF EATON. THE CONTENTS OF THIS DOCUMENT SHALL NOT BE-COME PART OF OR MODIFY ANY CONTRACT BETWEEN THE PARTIES.

In no event will Eaton be responsible to the purchaser or user in contract, in tort (including negligence), strict liability or otherwise for any special, indirect, incidental or consequential damage or loss whatsoever, including but not limited to damage or loss of use of equipment, plant or power system, cost of capital, loss of power, additional expenses in the use of existing power facilities, or claims against the purchaser or user by its customers resulting from the use of the information, recommendations and descriptions contained herein.

Product Registration

PLEASE REGISTER YOUR PRODUCT

By registering your product you’re registering for the warranty in addition to receiving important update information.

You can register your product in one of two ways:

1. Go online to: www.eaton.com/powerxpert and click on Power XpertProduct Registration to register your product.

2. Fill out the product registration information below and fax this page to 919-431-6240.

Product:__________________________________________________________

Product Model or Version Number:_____________________________________

Product Serial or License Number:_____________________________________

Company:________________________________________________________

Your Name:_______________________________________________________

Address:_________________________________________________________

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Table of Contents

1 Introduction ..............................................................................1

1.1. About this Manual ................................................................................... 11.2. Comparison of Meter Versions ................................................................ 11.3. Applicability ............................................................................................. 21.4. Power Xpert Software Subscription ........................................................ 51.5. AC Power Measurement Concepts Used in this Manual ........................ 71.6. Feature Comparison between Power Xpert Meter Models ...................131.7. Warranties ...............................................................................................15

2 Quick Start Guide for the Meter Module .............................. 17

2.1. Safety Precautions .................................................................................172.2. Power Supply Connections ................................................................... 182.3. VT , VX & CT Connections ................................................................... 202.4. Establishing Communications between the Meter Module and the Optional Graphic Display Module ................................................................ 212.5. Operating the Display Module ............................................................. 232.6. Programming the Meter Module using the Embedded Web Server Interface ...................................................................................................... 242.7. Programming the Meter Module via the Optional Communications Expansion Card ........................................................................................... 25

3 Installation ..............................................................................29

3.1. Mounting ............................................................................................... 293.2. Mounting the Power Xpert Meter and Display Separately ................... 303.3. Display Mounting .................................................................................. 303.4. Meter Mounting ................................................................................... 303.5. Mounting the Power Xpert Display and Meter as a Single Unit ........... 303.6. Wiring of CT & VT Connections ............................................................ 343.7. CT & VT Connector Installation on the Power Xpert .............................. 363.8. MeterDimensions ................................................................................. 373.9. WIRING ................................................................................................. 413.10. Fuses .................................................................................................. 413.11. Hipot and Megohm (Megger) Testing .................................................. 413.12. Communication Wiring ....................................................................... 423.13. RS485 Network .................................................................................. 433.14. RS485 Cable Characteristics ............................................................... 433.15. RS485 Wiring Basics ........................................................................... 433.16. LEDs ................................................................................................... 563.17. Display Link Addressing ....................................................................... 573.18. Java JRE PC Installation ..................................................................... 573.19. Comm Reset ....................................................................................... 57

4 Introduction to Web Server Screens .....................................59

4.1. Home, Meter, Power, Quality, Energy, I/O, Events & Setup Screens ... 604.2. The Meter Main Screen ........................................................................ 624.3. The Power Main Screen ........................................................................ 634.4. The Quality Main Screen ....................................................................... 634.5. The Energy Main Screen ...................................................................... 644.6. Selecting Other Devices From The Events Screen ............................... 654.7. Setup and I/O Screens .......................................................................... 654.8. I/O Screen ............................................................................................ 66

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5 Introduction to the Local Graphical Display ........................69

5.1. The Main Screens.................................................................................. 705.2. Navigating from one Main Screen to another ....................................... 715.3. The Back Button .................................................................................... 715.4. Accessing Details From All Main Screens ............................................ 725.5. The Meter Main Screen ........................................................................ 725.1. The Power Main Screen .........................................................................745.2. The Quality Main Screen ........................................................................745.3. The Events Main Screen ....................................................................... 755.4. The Setup Main Screen..........................................................................76

6 Functions on the Web Server Pages .....................................79

7 Functions on the Graphical Display .................................... 101

7.1. Overview ..............................................................................................1017.2. Meter ...................................................................................................1027.3. Energy ..................................................................................................1087.4. Quality .................................................................................................. 1117.5. Fast Transient (Available on the 8000 Series). ............................................... 1187.6. Subcycle Disturbance ...........................................................................1187.7. Locating Events .....................................................................................118

8 Setup on the Web Server Pages .........................................121

8.1. Overview ..............................................................................................121

9 Setup on the Graphical Display .........................................157

9.1. Log In ...................................................................................................1589.2. Quick Setup .........................................................................................1599.3. Meter Setup and Commissioning ........................................................1619.4. “Setup” This Display (Screen contrast, etc.) ........................................1629.5. Network, Firmware & Product Information .........................................1639.6. Password Setup ...................................................................................164

10 Firmware Upgrade ..............................................................165

10.1. Locating & Upgrading System Firmware on the Web ........................16510.13. Upgrading From a PXM4000 to a PXM6000 ....................................169

11 Troubleshooting & Maintenance ........................................171

11.1. Level of Repair ....................................................................................17111.2. Warnings! ...........................................................................................17111.3. Maintenance and Care .......................................................................17111.4. Calibration ...........................................................................................17111.5. Technical Assistance ..........................................................................17111.6. Return Procedure ...............................................................................17211.7. Resetting the Meter to Factory Defaults (Web Browser) ....................17211.8. Com Reset Switch ..............................................................................17211.9. Operating in Safe Mode ....................................................................17311.10. Troubleshooting Matrix ......................................................................173

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12 Glossary .............................................................................. 181

A MODBUS Communication ................................................. 185

A.1. Modbus Register Mapping ................................................................. 185A.2. Register 2001 (Invalid Object Access Configuration) ......................... 185A.3. Register 2002 (Floating-Point Data Register Configuration) .............. 185A.4. Register 2003 (Fixed-Point Data Multi-Register Configuration) ......... 185A.5. Register 2901 (Controls – Modbus RTU) ........................................... 186A.6. Register 2921 (Time/Date) ................................................................ 186A.7. Register 4607, 4719 (duplicate addr) (ProductID) {0x0000200B} ......... 186A.8. Register 4609 (Product Status) ......................................................... 187A.9. Register 4610 (Cause of Status) ........................................................ 187A.10. Registers 4611-6332 (Real-Time Measured Values) .......................... 188A.11. Register 11000+ (Real-Time and Historic Meter Data) ...................... 188A.12. Types of Data .................................................................................... 188

B Standard & Extended Modbus Register Maps .................. 191

B.1. Standard Modbus Register Map ..........................................................191B.2. Extended Modbus Register Map ........................................................193B.3. Minimum and Maximum Register Map ..............................................210B.4. I/O Register Map .................................................................................214B.5. Appendix E – Event Trigger Register Map ..........................................215B.6. Event Log Register Map ..................................................................... 218B.7. Trend and Profile Query Register Map ................................................ 220B.8. Latest Min/Max/Avg Register Map .................................................... 221B.9. Latest Demand Profile Register Map ................................................. 231

C SNMP Communication ........................................................235

C.1. SNMP in Power Xpert Meter .............................................................. 235

D Diagnostics ..........................................................................237

D.1. Battery Status ..................................................................................... 238D.2. System Log ........................................................................................ 239D.3. Event Count ....................................................................................... 240D.4. Communications - Ethernet Status .................................................... 241D.5. Communications - Ethernet Expansion Status ................................... 241D.6. Communications - COM0, COM1, COM2, COM3 (Slave) ................. 242D.7. Communications - COM1, COM2, COM3 (Master) ............................ 243D.8. Communications - I/O Internal Input Status ....................................... 245D.9. Communications - I/O Internal Output Status .................................... 245

E Option Cards .........................................................................247

E.1. Power Xpert Meter Option Cards ....................................................... 248E.2. Optional I/O Card ............................................................................... 249E.3. 1ms Time Stamping of Digital and Sub-Cycle Disturbance Events .... 250E.4. NTP Time Server ............................................................................... 250E.5. Satellite Time Reference (Cyber-Sciences STR-100) ........................... 251E.1. PXIO-B ................................................................................................ 251E.6. Communications Expansion Card (PXMCE card) .............................. 252E.7. Communication Ports (PXMCE card) .................................................. 253

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F Specifications .......................................................................255

G Standard Cards ...................................................................263

G.1. Power Xpert Meter Cards ................................................................. 264G.2. Communication Main (PXMCM) Card ............................................... 265G.3. PXMCM Com 0 and Com 1 RS485 bias resistors (Terminals CM3, CM5) ............................................................................................. 266G.4. 24V Source Outputs CM4 & CM6 ................................................... 268G.5. Power Supply Card PXMPS-1 ........................................................... 269

H Data Files ..............................................................................271

H.1. Accessing the Files ............................................................................. 271H.2. COMTRADE Files .............................................................................. 271H.3. Energy Logs ....................................................................................... 272H.4. Trend Logs .......................................................................................... 273

I Root Certificate Authority Installation .................................279

I.1. Installing Root CA with Microsoft Internet Explorer 6 and 7 ................ 279I.2. Installing Root CA with Mozilla Firefox ................................................ 282

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1 Introduction

1 INTRODUCTION

The Eaton Power Xpert PXM 4000/6000/8000 Meter is a multifunctional revenue-accurate power meter providing power quality analysis. It consists of a panel-mounted Display Module and a Base Meter Module that can be attached to the Display Module or mounted remotely. The Power Xpert Meter is a multi-processor based electrical distribution system monitor providing extensive:

• Metering

• Trending

• Logging

• Waveform capture

• Transient capture

• Remote input monitoring

• Control relaying/Alarming

• Communication capabilities

• Built-in Web server for browsing via the internet

In addition, it incorporates a number of value added features such as self-learning, adaptive report-ing, networked display, user levels, intuitive graphic displays, setup wizards and user text descrip-tions.

1.1. About this Manual

This technical document is the user manual for the installation, operation and unit level mainte-nance of the Eaton Power Xpert Meter. This document is intended for authorized and qualified per-sonnel who use the Power Xpert Meter. Please refer to the specific WARNINGS and CAUTIONS in this section before proceeding. If you require additional information, contact your Eaton Electrical representative. Technical Support is available 24 hours a day with our Power Quality Technical Support team at 1-800-809-2772, option 4 / sub-option 1. You can also email the team at [email protected] or visit us on the Web, www.eaton.com and follow the Products link.

1.2. Comparison of Meter Versions

This Instruction Manual covers the PXM 4000/6000/8000 series. Introduced in 2010, the PXM series includes significant Microprocessor and Memory upgrades from the PX series introduced in 2006. To determine the series, check the Model number printed on the product label located on the left side of the meter, as shown below.

IM02601004E www.eaton.com

1 Introduction

Improvements: • Internal RAM - from 32 MB SDR SDRAM to 256 MB DDR2 SDRAM• Data Storage - increased from a 512 MB (std)/1GB(option) to a fixed 2/4/8 GB for PXM

4000/6000/8000, respectively.• Waveform Capture - increased storage sample from 256 samples/cycle to 512 samples/cycle at

60 Hz. Delta-sigma over-sampling increased from 1024 samples/cycle to 4096 samples/cycle.• Transient Capture Resolution - increased from a 10-bit A/D to 14-bit A/D on PXM 8000• Maximum Operating Temperature - increased from 60° C to 70° C• Com Reset Button - added to restore Ethernet and other communications to the factory defaults• Mode Switch Selections - added troubleshooting mode to evaluate the system and connectivity.Items Remaining the Same: • Wiring• I/O and communications expansion cards• Local Display• Graphical User Interface• Panel mounting brackets• Old PX .zip setting files can be loaded into the PXM, which updates its format Other Changes:• Meter display includes blue highlights, top and bottom, as shown below. • Meter base includes blue highlights, on bottom, as shown below.

• Model number has been changed from PX to PXM, and previous digit for the memory option will be “1” to represent standard communiction

• Power supply module has changed and cannot be used with first generation meters and vice versa

• Low voltage (24-48 VDC) DC version is not available for the PXM• Real-time clock - 10-year battery moved from power module to coreboard • The new PXM firmware has been written to be compatible with the older PX meters on its

RS485 subnetwork; however, the PXM must be the master in this arrangement. This Instruction Manual describes the PXM 4000/6000/8000 series. For instructions and specifica-tions on the PX4000/6000/8000 series refer to IB02601003E.

1.3. Applicability

This manual applies to the Power Xpert Meter and display in the following configurations:Power Xpert PXM4000 MeterPower Xpert PXM6000 Meter


1 Introduction

Power Xpert PXM8000 MeterPXD-MMG Graphic Display ModulePX-PMBA - Panel Mounting Bracket AssemblyPXMCE-B Communication Expansion CardPXMIO-B Digital I/O CardSafety PrecautionsAll safety codes, safety standards and/or regulations must be strictly observed in the installation, operation and maintenance of this device.

WARNINGS refer to a hazardous situation which, if not avoided, could result in death or serious injury.CAUTIONS refer to a hazardous situation which, if not avoided, could result in equipment damage.

WARNINGSSHOCK HAZARDS: IMPROPER INSTALLATION CAN CAUSE DEATH, INJURY AND/OR EQUIPMENT DAMAGE. Follow all Warnings and Cautions. Completely read and understand the information in this docu-ment before attempting to install or operate the equipment. Improper wiring could cause death, injury and/or equipment damage. Only qualified personnel are to service the Power Xpert Meter. TROUBLESHOOTING PROCEDURES MAY REQUIRE PROXIMITY TO EXPOSED ENERGIZED (LIVE) ELECTRICAL WIRING AND/OR PARTS WHERE THE HAZARD OF FATAL ELECTRIC SHOCK IS PRESENT. Exercise extreme care to avoid injury or death. Always disconnect, lock-out and tag the current and voltage sources and the control power supply circuit before touching the connections or compo-nents on the rear face of the meter base unit.

FAILURE TO GROUND THE POWER XPERT METER MAY RESULT IN INJURY, DEATH OR EQUIPMENT DAMAGE.

Properly ground the Power Xpert Meter during installation.

VOLTAGE

200ms rms and 1 cycle rms with half-cycle updates:Van, Vbn, Vcn, Vng, Avg VLN,Vab, Vbc, Vca, Avg VLL,AUX (Vab, Vbc, Vca, Avg VLL) [PXM42xx, PXM62xx, PXM82xx]Min/max with timestampWaveformSub-Cycle Disturbance CaptureFast-Transient Capture 6Msps/channel (Vag, Vbg, Vcg, Vng) [PXM 8xxx]Symmetrical Components [PXM6xxx, PXM8xxx]Phasor Diagram

CURRENT

200ms rms and 1 cycle rms with half-cycle updates:Ia, Ib, Ic, In, Ig, Avg I (abc)

Min/max with timestampWaveformSymmetrical Components [PXM6xxx, PXM8xxx]Phasor Diagram


1 Introduction

POWER

200ms rms:Real per-phase and system (kW)Apparent per-phase and system (kVA)Reactive per-phase and system (kvar)Demand

Real Forward, Reverse, Net, Sum (kW)Apparent (kVA)Reactive Delivered, Received, Net, Sum (kvar)Current (Amperes)

POWER FACTOR

Apparent (True) per-phase and system Displacement per-phase and system

FREQUENCY (OF VAG)

10-100Hz and 350-450Hz

ENERGY

Real Forward, Reverse, Net, Sum (kWh)Apparent (kVAh)Reactive Delivered, Received, net, Sum (kvarh)Current (Ah)Time of Use Rates A, B, C, D, Total (Energy and Demand)Energy Profile (2 month comparison)

QUALITY

Power Quality Index (worst of 6 weighted PQ components)dv/dt count, %TDDi, %THDv (all models); Sag level , Swell level and Flicker (6000 and 8000 series only),Indicates Normal, Caution, and Alert levelsLatest 10 minutesLatest 24 hours

K-Factor of phase currentCrest Factor of phase currentFlicker Perceptibility, Pst, and Plt of Van, Vbn, Vcn, Vab, Vbc, and Vca [PXM 6xxx, PXM 8xxx]Harmonics

Ia, Ib, Ic, In, Van, Vbn, Vcn, Vab, Vbc, VcaHarmonic Distortion in Amps, Volts, %TDD, %THD (total available on all models)Harmonic Distortion in Amps, Volts, %TDD, %THD (even, odd, inter-haermonic available on the 6000 and 8000 Series Harmonic spectrum (1-85th harmonic)Inter-Harmonic spectrum (5Hz resolution) [availale on the 6000 and 8000 Series]


1 Introduction

TREND

Each of 145 attributes trended automatically for min, max, and average at 5 different intervals.Five years of 5-minute trend data is available as sets of weekly files.

Zoom 1: Every 5 minutes for 48 hours (2 days) [9 weeks as .csv files via FTP] Zoom 2: Every 15 minutes for 192 hours (8 days)Zoom 3: Every 1 hour for 28 days (4 weeks)Zoom 4: Every 8 hours for 56 weeks 13 months)Zoom 5: Every week for 44 months

EVENTS

Timestamped Waveforms and Captured ParametersITIC curve for Sag and Swell events (available on the 6000 and 8000 Series)Log of triggered events, new min/max, resets, and setting changes21 Waveform channels; 4 line-to-ground Voltage, 3 line-to-neutral Voltage, 3 line-to-line Voltage, 5 phase Amps, 3 AUX line-to-line Voltage [PXM42xx, PXM62xx, PXM82xx], and 3 AUX line-to-ground Voltage [PXM42xx, PXM62xx, PXM82xx]

OUT OF LIMITS EVENT TRIGGERS

Any per-phase or system value in the following categories:Current, Voltage, Power, Power Factor, Frequency, Harmonic Distortion, 9s of Availability/Compliance calculation based upon any/all triggers selected for Performance (all models)Flicker, Voltage Unbalance, and Current Unbalance. Symmetrical component (available on the 6000 and 8000 Series)

DEMAND OVERLOAD TRIGGERS

Real Forward, Reverse, Net, Sum (kW)Apparent (kVA)Reactive Delivered, Received, Net, Sum (kvar)Current (Amperes)

SUBCYCLE DISTURBANCE TRIGGERS

Absolute and dv/dt thresholds based upon 30.72ksps

FAST TRANSIENT TRIGGERS

Absolute and dv/dt thresholds based upon 6Msps (available on the 8000 Series)

1.4. Power Xpert Software Subscription

Each meter can be joined to a single Power Xpert Software system via subscription. Do not sub-scribe to the same meter from multiple instances of Power Xpert Software.


1 Introduction

Description Catalog #Digital I/O Card: 8 digital Input, 2 Solid Output, 3 Relay Output PXMIO-BComms Expansion Card: Ethernet 100FX, 10/100T, RS-485, RS-232 PXMCE-BGraphic Display Module PXD-MMGPanel Mounting Bracket assembly required for back-to-back meter to display mounting PX-PMBAPower Expert Meter 4000 to 6000 License Upgrade Key PXM-4KUPG

Note: Only cards with a catalog number beginning with PXM are compatible with thePXM4000/6000/8000 meter.

Power Xpert Meter PXM 4000/6000/8000 Meter Accessories

Power Xpert® Meter 4000/6000/8000 Catalog Numbering System

PXM 8 1 0 5 A B 1 B

Card Slot 3 Con-gur ation

A = No Card OptionB = I/O Option Card (8 Digital Inputs, 2 Solid State Outputs, 3 Relay Outputs)


A = No Card OptionB = Communication Expansion Card w/100/1000Base-T, 100F, RS-485, RS-232 Ports


1 = Standard Communications Module with RS-485

Model Series

4 = 4000 (Standard Power Quality), 2GB6 = 6000 (Enhanced Power Quality), 4GB8 = 8000 (Premium PQ w/ Transient Capture), 8GB

0 = Standard (V1, V2, V3, V4)2 = Standard Plus Auxilary (V6, V7, V8)

Voltage Input Con-gur ation

1 = Standard 100-240 VAC or 110-250 VDC Power Supply

Voltage Input Con-gur ation

The example above represents a PXM8000 Meter, with Standard AC Power Configuration, and with a Communication Expan-sion Card and I/O Option Card.

Catalog Numbering System


1 Introduction

1.5. AC Power Measurement Concepts Used in this Manual

There are three types of power systems we’ll discuss:• Single-Phase• Three-Phase• Poly-Phase

SINGLE-PHASE

Single-Phase power distribution systems are two-wire systems used to supply 120 VAC (measured from line-to-neutral). Such systems are typically used for lighting, heating, data equipment, and small appliances. This configuration is usually found in residential and of-fice environments. For higher loads, such as larger resistance heaters used in water heat-ers, electric dryers, and the like, three-wire, single-phase systems are used that provide 240 VAC (measured from line-to-line).

Two and Three-Wire Single Phase Wiring

LineNeutral

Line 1 Neutral Line 2

Single-Phase Power Equations

The following equations provide the basis for calculating Power (W), Reactive Power (VAR) and Apparent Power in single-phase systems. You’ll see these terms used through-out the manual when discussing AC power measurement. Power (W) within a two-wire, single-phase system is calculated as:

Where:V is PotentialI is Currentcos is the phase difference between the Current and the Potential.Power for a three-wire, single-phase system is calculated as:


1 Introduction

Where the phase difference between the Current and the Potential is the result of a non-resistive load, which can be either capacitive or reactive.Reactive Power (VAR) is defined as any additional power consumed by the load that doesn’t do any actual work. You can think of this as a measure of the inefficiency of the system. VAR is calcu-lated as:

Apparent Power (VA) is defined as the total power that’s delivered to the load. It’s the vector sum of the Power (W) and the Reactive Power (VAR).Power Factor (PF) is the ratio between Power (W) and the Apparent Power (VA). Ideally, the power factor should be 1; however, this can only occur if there are no inductive loads. In actuality, many loads are inductive and capacitors are installed to correct a poor Power Factor. Power Factor (PF) is calculated as:

THREE-PHASE

Three-phase is typically used for power transmission, but is also often used to power motors and other industrial or commercial equipment. In three-phase systems, three conductors carry three alternating currents of the same frequency. One conductor is the reference and the remaining con-ductors have their currents delayed by one-third and two-thirds of a cycle.

Three-Phase Current

Phase A Phase CPhase B

Typically, three-phase systems use either a Delta connection or a Wye conncetion, as shown in the following figure:

Typical Three-Phase Systems

B

A

C

A

N

BC

4-Wire “Wye” 3-Wire “Delta”


1 Introduction

The following equation defines the voltage levels between the phases:

Three-phase systems are distributed in different voltages, depending on load factors, which typi-cally are:• 208 VAC• 480 VAC• 2,400 VAC• 4,160 VAC• 6,900 VAC• 13,800 VAC

POLY-PHASE

To measure power in a poly-phase system, one must apply Blondel’s Theorem. This states that in a system having N conductors, N-1 properly connected meter elements will provide a measurement of electrical power. Properly connected means that all potential coils must have a common tie to the conductor to which there is no current coil. Typically, poly-phase systems are configured as either a Delta or a Wye connection.

UNDERSTANDING POWER CONCEPTS

The following defines power consumption, demand, power factor, waveforms, and harmonics.Consumption The total electrical energy used over a period of time. This is typically

measured in Wh (or more likely, kWh). It is defined by the following formula, which utilities use to calculate power consumption within a specified billing period (T). W in this equation is instantaneous power.

Wh=WXT

Demand The average energy consumed over a specified time period. Utilities deter-mine exactly what that period of time is, and it’s typically either 15 or 30 min-utes. This measurement deviates from average consumption, which forces utilities to provide sufficient generating capacity to satisfy this measurement.

Power Factor A poor power factor, transferred over a distribution network, results in a loss of energy. Utilities monitor this and penalize customers for poor power factor in an effort to force them to improve their systems.

Waveforms Ideally, power distribution systems should exhibit sinusoidal waveforms for both current and voltage. However, real-world applications have power consuming devices that create distortions. Such distortions are harmonics of the fundamental frequency. Harmonic distortion is something to avoid as it poses a safety hazard, reduces the working life of distribution transformers, and interferes with electronic equipment.

Some of the terms and concepts you’ll encounter in this manual are: Sinusoidal Waveforms: This is defined by the following equation:

Distorted Waveforms: This is defined by the following:


1 Introduction

Percent of Total Hamonic Distortion: Defined by the following:

SIGN CONVENTIONS

The sign of Watts, vars and PF are related to the phase angle between the voltage and current waveforms. As shown, the PXM 4000/6000/8000 meters indicate positive Watts, vars and PF for consumed power. Within this standard, motors consume both Watts and vars (i.e. a lagging current as measured at the load has +W, +var and +PF).For power measured at the source, generated Watts and vars are negative, but the sign of PF is consistent with what it is as measured at the load.

A 3-phase motor load is illustrated in the following phaser diagram with an ABC counterclockwise rotation.


1 Introduction


1 Introduction

SYMMETRICAL COMPONENTS

Symmetrical components are commonly used for analysis of three-phase electrical power systems. Phase vectors are expressed as sets of phasors, either as real or quadrature or magnitude and phase. For example, a vector for three-phase voltages could be written as Vabc.

.

and the three symmetrical component phasors arranged into a vector as V012.:

where Vo is the zero-sequence of component (the portion of voltage with no rotation)where V1 is the positive-seqience component (the portion of voltage with abc rotation)where V2 is the negative-sequence component (the portion of voltage with abc rotation).

A phase rotation operator ...... is defined to rotate a phasor vector forward by 120 de-grees. As a result ...... 2 is a phase rotation of 240 degrees.

A materix “A” can be defined using this operator to transform the phase vector into sym-metrical components.

The phase voltages are generated by the sequence equation: Vabc = A • V12.Conversely, the sequence components are generated from the analysis equations V012 = A-1 • Vabc .

While the analysis of symmetrical components is primarily focused on voltage, the analy-sis of current is equally valid.

VOLTAGE AND CURRENT UNBALANCE

When individual phases of a three-phase system diffeer, an unbalance results. Further-more, harmonic distortion can also result in unbalance. The measure of unbalance is the ratio of the negative-sequence to the positive-sequence components and is represented as a percentage.


1 Introduction

Voltage Unbalance = V2/V1 * 100%Current Unbalance = I2/I1 * 100%

Note that V1, V2, I1 and I2 are symmetrical component values that should not be con-fused with Va, Vb, Ia, Ib, or with similarly labeled input terminals on the meter.

1.6. Feature Comparison between Power Xpert Meter Models

FEATURE PXM4000 PXM6000 PXM8000Trend logging • • •Load Profile • • •Event logging • • •MEMORY & STORAGE2 GB Standard Memory •4 GB Standard Memory •8 GB Standard Memory •HARMONICSHarmonic levels 256 256 256Total Harmonic Distortion (THD) • • •Delta-Sigma D/A Conversion Technology • • •Harmonics over-sampling (4096 samples per cycle)* • • •Anti-Alias Filtering • • •Individual Harmonics • • •Total Demand Distortion (TDD) • • •Even, Odd and Interharmonics • •HIGHLIGHTSSub-cycle disturbance capturing • • •dV/dt triggers for sub-cycle oscillatory tran-sients • • •Absolute Threshold and dV/dt triggering • • •Power Quality Index - Standard (includes dv/dt count, %TDDi and %THDv) • • •Power Quality Index - Enhanced (includes Standard Index plus Sag level, Swell level and Flicker)

• •

Flicker calculations • •Automatic trigger setting • •Automatic event severity analysis • •Event Severity counters • •ITIC (Information Technology Industry Council), previously CBEMA performance curve • •


1 Introduction

FEATURE PXM4000 PXM6000 PXM8000Custom ITIC (CBEMA) plot with individual event magnitude and duration • •Event Calendar View • •Events Timeline View • •Sequence of events and events plot on wave-form • •Power Quality Index - Premium (includes Enhanced Index plus counts of impulsive transients)

•

HIGH SPEED TRANSIENT CAPTURE & DETECTION6 MHz capture of impulsive transients •Transient capture duration: ~20ms/6MHz ~120ms/1MHz •Waveform recorded at 100,000 samples per cycle •Three-phase voltage and neutral-to-ground fast transient capture •

* Delta-Sigma A/D oversampling rate Note: These specifications are subject to change without notice and represent the maxi-mum capabilities of the product with all options installed. This is not a complete feature list. Features and functionality may vary depending on selected options and product model. Please refer to the technical data sheet for detailed specifications.

The standard version of the Power Xpert Meter Industry Canada version of the Power Xpert Meter (pending approval).

PX/PXM Seal Kit -Measurement Canada (66A2294G01)


1 Introduction

1.7. Warranties

WARRANTY FOR PRODUCTS

Seller warrants that the Products manufactured by it will conform to Seller’s applicable specifica-tions and be free from failure due to defects in workmanship and material for one (1) year from the date of installation of the Product or eighteen (18) months from the date of shipment of the Product, whichever occurs first. In the event any Product fails to comply with the foregoing warranty Seller will, at its option, either (a) repair or replace the defective Product, or defective part or component thereof, F.O.B. Seller’s facility freight prepaid, or (b) credit Buyer for the purchase price of the Product. All warranty claims shall be made in writing. Seller requires all non-conforming Products be returned at Seller’s expense for evaluation unless specifically stated otherwise in writing by Seller. This warranty does not cover failure or damage due to storage, installation, operation or maintenance not in conformance with Seller’s recommendations and industry standard practice or due to accident, misuse, abuse or negligence. This warranty does not cover reimbursement for labor, gaining access, removal, installation, temporary power or any other expenses, which may be incurred in connection with repair or replacement. This warranty does not apply to equipment not manufactured by Seller. Seller limits itself to extending the same warranty it receives from the supplier.


2 Quick Start Guide for the Meter Module

2 QUICK START GUIDE FOR THE METER MODULE

2.1. Safety Precautions

All safety codes, safety standards and/or regulations must be strictly observed in the installation, operation and maintenance of this device.

WARNINGS refer to instructions that, if not followed, can result in death or injury.

CAUTIONS refer to instructions that, if not followed, can result in equipment damage.

WARNINGSSHOCK HAZARDS: IMPROPER INSTALLATION CAN CAUSE DEATH, INJURY AND/OR EQUIPMENT DAMAGE. Follow all Warnings and Cautions. Completely read and understand the infor-mation in this document before attempting to install or operate the equipment. Improper wiring could cause death, injury and/or equipment damage. Only qualified personnel are to service the Power Xpert Meter 4000/6000/8000 and Graphic Display.

TROUBLESHOOTING PROCEDURES MAY REQUIRE PROXIMITY TO EXPOSED ENERGIZED (LIVE) ELECTRICAL WIRING AND/OR PARTS WHERE THE HAZARD OF FATAL ELECTRIC SHOCK IS PRESENT. Exercise extreme care to avoid injury or death. Always disconnect, lock-out and tag the current and voltage sources and the control power supply circuit before touching the connections or components on the rear face of the Power Xpert Meter 4000/6000/8000 and Graphic Display. FAILURE TO GROUND THE POWER XPERT METER MAY RESULT IN DEATH, IN-JURY OR EQUIPMENT DAMAGE. Properly ground the Meter Module during installation.IMPROPER ASSEMBLY AND INSTALLATION OF THE CT TERMINAL BLOCK AND STRAIN RELIEF HOOD MAY RESULT IN OPEN CIRCUITED CTS AND EXPOSURE TO DANGEROUS VOLTAGES WHICH MAY RESULT IN SEVERE INJURY OR DEATH.Terminal block hoods are provided with the metering current and voltage terminal blocks. The current terminal block retaining screws are part of the matching hood assembly. The current terminal block and hood assembly must be properly installed with retaining screws to secure the current terminal block to the meter housing to prevent exposure to shock hazard.



2.2. Power Supply Connections

1. Connect the Power Supply (PXMPS-1) The Meter Module is powered using a 100-240Vac or 110-250Vdc (PXMPS-1) standard power supply.

• PS1-3 connected to ground• PS1-2 connected to Neutral (Vac) or (-)Vdc• PS1-1 connected to Line (Vac) or (+) Vdc

Fabricate a power cord of suitable length and connect to the power supply via the Power Supply Connection shown in Figure 1. (Note: The Green Health LED should blink at a slow rate (once per second). If it blinks at a faster rate, see the Troubleshooting chapter in the manual. The Red Status LED will blink if unacknowledged or uncleared events exist.

PXMPS-1 Card

Power Supply ConnectionPS1-3PS1-2PS1-1

Health & StatusLEDs

Figure 1: Meter Module Power Supply Connection & LED Locations

Power LED

Protective EarthGround



2. Configure the Security Mode Dip Switches:

3. Planning CT and VT Connections (Figure 3)Determine your wiring requirements for the meter module. This quick start guide will cover these basic wiring configurations:

• 3-Phase, 3-Wire Delta( Up to 600 V L-L, 347 L-N) 3CTs• 3-Phase, 3-Wire Delta (Above Up to 600 V L-L, 347 L-N) 3CTs• 3-Phase, 3-Wire Delta (Above Up to 600 V L-L, 347 L-N) 2 CTs• 3-phase,4-Wire Y (Up to Up to 600 V L-L, 347 L-N) • 3-phase,4-Wire Y (Above Up to 600 V L-L, 347 L-N)

See Installation, for wiring diagrams.

DS-1 DS-2 DS-3OFF OFF ON is

Normal. OFF is Safe Mode

No restrictions (user ID/Password re-quired)ADMIN/ADMIN accepted for 15 minutes after boot-up

OFF ON ON is Normal. OFF is Safe Mode

Medium Security - Energy & Demand resets prohibited

ON OFF ON is Normal. OFF is Safe Mode

High Security- Configuration changes; Energy & Demand reset prohibited

ON ON ON or OFF

Factory Test Mode - The meter should never be operated in this mode. The meter will indicate that it’s in factory test mode through a repeating series of three flashes on the red Status LED



Figure 2: Meter Module’s Dip Switches & Tamper Seals

Tamper Seals

3

2

1

DIP Switches

ON OFF

2.3. VT , VX & CT Connections

VT Terminal Voltage Connections:Voltage Inputs can accept up to 600Vac L:L / 347VL:G direct. A PT with a 120V secondary is required If this rating is exceeded. Primary settings are 120-500,000, for a PT ratio of 120:120 to 500000 to 120. It is strongly recommended that the Voltage Inputs be con-nected to the Meter Module by way of properly rated disconnect switches.

• VTV1 = Line 1 or Va• VTV2 = Line 2 or Vb• VTV3 = Line 3 or Vc• VTV4 = Line 4 or Vn (neutral)• VTVR = Metering Reference Ground

VX Optional Auxiliary Voltage Connections:• VXV6 = Line 1’ or Va2• VXV7 = Line 2’ or Vb2• VXV8 = Line 3’ or Vc2

CT Terminal Connections:Current Inputs accepts a 5-amp secondary with available Primary settings of 5-9999, for a CT ratio of 5:5 to 9999:5. It is strongly recommended that the Current Inputs be connected to the Meter Module by way of a shorting block.

• Line 1 CT connected to Terminals 11 (polarity mark) & 12 (return)• Line 2 CT connected to Terminals 21 (polarity mark) & 22 (return)• Line 3 CT connected to Terminals 31 (polarity mark) & 32 (return)• Neutral CT connected to Terminals 41 (polarity mark)& 42 (return)• Ground CT connected to Terminals 51 (polarity mark)& 52 (return)



2.4. Establishing Communications between the Meter Module and the Optional Graphic Display Module

1. Establishing communication between the Graphic Display Module and Meter Module:A. Using an RS485 cable, connect COM 0 (Figure 4) on the back of the Display Module to COM 0 (Figure 5) found on the Meter Module (RS485 Comms). See table below and the Cable Specifications Table for wiring. Display PXCMDescription Terminal Cable Terminal DA DG1-1 TP CM5-1DB DG1-2 TP CM5-2SH DG1-3 SDW CM5-3TP=Twisted PairSDW = Shield Drain Wire

B. Connect CM6 (Figure 5) located on the CM card to DG2 (Figure 4) on the Display Module to supply power (24V) to the Display Module. See table below for wiring.

Display PXCMDescription Terminal Cable Terminal SH DG2-1 OSCS CM6-124+ DG2-2 TP CM6-2COM DG2-3 TP CM6-3Gnd DG2-4 To local panel groundOSCS=Optional Separate Cable Shield(OSCS used for separate power and data cables)

Figure 3: CT & VT Connections

VX Connections

CT Connections

VT Connections



DO NOT HIPOT / DIELECTRIC TEST

2) THIS DEVICE MUST ACCEPT ANY INTERFERENCE RECEIVED, INCLUDING INTERFERENCE THAT MAY CAUSE UNDESIRED OPERATION.

THIS DEVICE COMPLIES WITH PART 15 OF THE FCC RULES. OPERATION IS SUBJECT TO THE FOLLOWING TWO CONDITIONS:1) THIS DEVICE MAY NOT CAUSE HARMFUL INTERFERENCE, AND

CW

Power Com 0

3

SH

1234

SH

CO

M

24

+

DG2-12

DB

DA

DG1-

Display Link24VDC Input

Customer Satisfaction for Technical Supportwww.EatonElectrical or <http://www.EatonElectrical.com

1-800-809-2772 or 1-414-449-7100

E185559

MEASURING EQUIPMENT20NL

Catalog#: PXD-MMG

Serial#: XXXXXXStyle#: 66D2117G01

Power Supply: 24 VDC (+/-20%)SELV, 8W MAX.

MADE IN USA

Date Code: WYYYYMMDDRev: XXX

Oper Temp: -20 TO 60°C

MAC Address (Front): XX:XX:XX:XX:XX:XXMAC Address (Bottom): XX:XX:XX:XX:XX:XX

DG1 Display Link COM 0

DG2

C. Set the Rotary Switch (Figure 5) located on the side of the Meter Module unit to a number 1 through 16.NOTE: The Display Module can communicate to a maximum of 16 Meter Modules by con-necting the Meter Module’s COM 0 together following basic RS485 wiring specifications. Each Meter Module will need to be uniquely addressed using the Rotary Switch.

Figure 4: Display Module Connections to Base Unit

Figure 5: Meter Module Connections to Display

Rotary SwitchCM5-COM 0

CM6 24VSource



2.5. Operating the Display Module

The Display Module (Figure 6) is an easy-to-use, intuitive interface to the Meter Module. It has the following features:

• Navigation Dial - Turn clockwise and counterclockwise to select (highlight) options on the screen. Once highlighted, push dial to get more information about the topic.

• Back Button - Push to return to the previous selection.

Display Health LED - If Display Module is powered-up, the LED will blink slowly (1/sec).

Turn to Highlight

BACK

Push to Select Hold in for Help

EventsHealthPower Xpert

Figure 6: Display Module Controls

HealthLED

BackButton

Meter EventLED

NavigationDial



2.6. Programming the Meter Module using the Embedded Web Server Interface

NOTE: The set up of the Ethernet ports on the CE card must be done through the local configuration port of the CM card or with the display. After the CE Ethernet port is config-ured, the meter can be programmed remotely through the LAN/WAN connection.1. Connecting a laptop to the meter module using the local Ethernet browser interface

CMI:A. Install Java (if not already on the PC). To do this, download the latest version

of Java J2SE JRE (Java Runtime Environment) from www.java.sun.com and install it.

B. Connect the Laptop to the Meter Module via CM1 port (see figure 7 below) using a UTP Cat5 Patch Cable. Note that the IP address of the CM1 port is permanently configured to be 192.168.1.1.

C. Set the laptop’s IP address to 192.168.1.100 by completing the following steps:

• Click Window’s Start. Then click Settings > Control Panel (Windows 2000) or Control Panel (Windows XP/Vista).

• In Control Panel, click Network and right-click Local PC Area Connection. Select Properties from the shortcut menu.

• In the Properties dialog, select Internet Protocol (TCP/IP) and click the Proper-ties button.

• In the Internet Protocol (TCP/IP) Properties window, select “Use the following IP address” and then enter the following IP address 192.168.1.100, with a Subnet Mask set to 255.255.255.0.

• Click OK. Launch Internet Explorer and then navigate to http://192.168.1.1, then go to

Step 2 in Section 2.6.NOTES: When connected to a laptop, the Link LED will illuminate and, when communi-cating, the TXRX LED will flicker.For PXCM Cards, the local configuation port may require the use of a UTP Cat 5 cross over cable. The PXMCM card accepts a standard Cat 5 patch cable.

Figure 7: Connect Laptop to Meter Module

Link LEDCM1 TXRX LED



2.7. Programming the Meter Module via the Optional Communications Expansion Card

The Optional Communications Expansion (CE) card (see figure 8 below) provides LAN/WAN Web Ethernet communication via either Fiber (CE1) or UTP/STP Cat5 cable (CE2). It also provides communication via Modbus RTU (CE3 & CE4 – see Appendix A of the manual for Modbus instructions). Note: The CE card is generally installed by the factory at time of manufacture. If the card is installed as an after sale option, follow instructions for physical installation that accom-pany the card or refer to the manual. To set up the card follow these steps:

A. The meter ships DHCP and CE2 enabled. Connect the standard cable (blue) from CE2 to network. Because DHCP is enabled, the user must find the IP ad-dress via the Local Configuration port [Setup->Diagnostics->Communication->Ethernet] or Local Display.

NOTE: CE1/2 are multiplexed by setpoints.B. Power cycle the meter to initiate DHCP. If DHCP is not used, an IP address

will need to be assigned.

CE 1

Figure 8: Ethernet & Modbus Connections

CE Card CE 2

CE 3

CE 4



For further details about the following steps, refer to Setup on the Web Server Screens/Setup on the Local Graphical Display respectively.1. Start Internet Explorer. After “http:\\”, type in the IP address of the CE Ethernet port in

the address box and click OK. The Meter Webserver Home Page will be displayed. (If DHCP is enabled, the user must find the IP address via the Local Configuration port [Setup->Diagnostics->Communication->Ethernet] or Local Display).

2. On the Meter Webserver home page, click Setup Meter.

3. Login to the Meter Module by clicking on the Login/Change Users button.

4. Type the Name and Password. The defaults are: Name = admin and Password = admin. After entering the Name and Password, click OK.

Note: Without logging into the meter, data is read-only.

5. From the setup menu, click Quick Setup to display basic configuration setup.



6. Click Edit to make changes to these parameters.

7. Set the clock by clicking on Meter Setup & Commissioning > Clock > Edit.

Notes on Modbus support: The Optional Communications Expansion (CE) card also provides communication via Modbus RTU (CE3 & CE4 – see manual for Modbus instructions) The RS485 CE3 port supports Modbus RTU slave to a master monitoring system. The port defaults as a Master Gateway, which relays Ethernet Modbus TCP command to slave meters connected to the same RS485 link. The Modbus slave address may be set via the display module or with a web browser.


3 Installation

3 INSTALLATION

The Power Xpert Meter is designed to be installed, operated and maintained by ad-equately trained personnel. These instructions do not include all details, variations or combinations of the equipment, its storage, delivery, installation, checkout, safe operation or maintenance. Compliance with local, state and national regulations, as well as with industry standard safety practices for this class of equipment, is imperative. This chapter describes mounting, wiring, startup and miscellaneous details associated with the Power Xpert Meter. Every section should be reviewed prior to installing this device. WARNINGSHOCK HAZARD: VERIFY THAT ANY INCOMING AC POWER OR FOREIGN POWER SOURCES ARE TURNED OFF AND LOCKED OUT BEFORE PERFORMING ANY WORK ON THE POWER XPERT METER OR ASSOCIATED EQUIPMENT. Failure to do so can result in death, injury, or damage to equipment.

3.1. Mounting

It is recommended that the Power Xpert Meter is mounted in an electrical switchgear enclosure that is suitable for its environment. The display and meter modules may be mounted together or separately. The Power Xpert Meter is designed with flexibility in mind. While it is recommended that the display be door or panel mounted, the meter can be mounted remotely from the display on a flat surface or panel elsewhere in the enclosure. A mounting kit (#PX-PMBA) is available to permit mounting the display and meter modules together.

• To maintain proper ventilation, Power Xpert Meter must remain vertical at all times with 3 inches of clearance above and below the chassis. The meter also requires a minimum of 2 inches of clearance in front of the face plate for wiring clearance or 4 inches of clearance if fiber optic or RS232 connections are used.

• The display and meter should be installed in a Pollution Degree II environment.

• The display MUST be connected to earth ground.

• The meter should be protected from accidental contact with live terminals in the enclo-sure. A 1/8 inch steel panel or door, solidly grounded, is recommended.

• Before cutting the panel, check the required three-dimensional clearances for the meter case, particularly behind the panel (see the dimension drawings in this chapter). If mounting on a swinging door, check the swinging clearance of rear projections and wired connections. Remember to allow for extra space for all wiring, intermediate termi-nal strips, shorting blocks or any other required components.

• The Power Xpert Meter comes standard with the remote mounting brackets attached.

• The display comes standard with the required hardware, five #8-32 x .50 LG Phillips Pan head SEMS Screws, for mounting the unit to a door or panel.


3 Installation

3.2. Mounting the Power Xpert Meter and Display Separately

Because the display is typically mounted on an enclosure door, it is necessary to prepare a cutout in which it will be placed. The dimensions for this cutout with the mounting hole locations are shown in the panel cutout figure on page 40. Before cutting the panel, verify the clearances for the meter chassis to ensure it can be mounted in the desired location. The Power Xpert Meter dimensions are shown in the display and meter module figures starting on page 37. It is necessary to hold several tolerances when making the cutout and placing the holes for the mounting screws. The holes must be located within 1/16 in. of the drawing specifi-cations, and a .188 in. to 3/16 in. drill bit is recommended. To mount the Power Xpert Meter directly to a flat panel, as recommended, a panel cutout is not necessary. There are eight hole locations on the meter module mounting brackets; four circular holes and four keyholes. Either set will work for mounting. See the Power Xpert Meter figure for the hole sizes and locations. The display and meter come with stan-dard parts for mounting and installation. See above for a detailed description.

3.3. Display Mounting

Ensuring that the display gasket is in place, place the back of the display module through the panel cutout. Using the five #8-32X1/2 in. screws, attach the display to the panel. Install the top center screw first. Note that the panel must be smooth and flat to ensure a proper gasket seal.

3.4. Meter Mounting

Attach the meter to the flat panel using the four circular holes or the four keyholes previ-ously drilled into the panel.

3.5. Mounting the Power Xpert Display and Meter as a Single Unit

The customer must purchase a separate mounting kit (#PX-PMBA) for this feauture. Because the display is typically mounted on an enclosure door, it is necessary to prepare a cutout in which it will be placed. The dimensions for this cutout along the mounting hole locations are shown in the Power Xpert Display Panel Cutout figure on page 40. Before cutting the panel, verify the clearances for the meter chassis to ensure it can be mounted in the desired location. The meter dimensions are shown in the Power Xpert Meter Integral Mounting Arrangement drawings on the following pages. It is necessary to hold several tolerances when making the cutout and placing the holes for the mounting screws. The holes must be located within 1/16 in. of the drawing specifi-cations, and a .188 in. to 3/16 in. drill bit is recommended. Use the standard pieces supplied with the mounting kit (#PX-PMBA) to mount the Power Xpert Meter and Display as a single unit. Install the cable supplied in the mounting kit to connect the display module (DG1 & DG2) to the meter module (CM5 & CM6) on the PXMCM-X board.


3 Installation

Mounting the Power Xpert Display and Meter as a Single Unit, Con’t.

1) Place the display module through the panel cutout. Using one of the provided #8-32X1/2 in. screws, screw the display module to the panel at the top center point.

2) Place one of the provided display P-Back mounting brackets on the side of the display module and screw it into place using the two provided #8-32X1/2 in. screws.

Repeat this step to install the remaining Display P-Back Mounting Bracket.


3 Installation


3) Remove the key slotted mounting brackets from the back of the meter module.

4) Attach the Meter P-Back mounting brackets to the back of the meter with the #10-32X5/16 in. screws that were removed.

5) Slide the meter housing, with brackets attached, into the display brackets.


3 Installation


6) Screw the display and meter brackets together with the four #10-32X5/16 in. screws provided in the mounting kit.


3 Installation

3.6. Wiring of CT & VT Connections

Install the cable supplied in the mounting kit to connect the display module (DG1 & DG2) to the meter module (CM5 & CM6) on the CM-X board.The Power Xpert Meter models PXM4000, PXM6000, and PXM8000 series are provided with terminal blocks for CT and VT connections. Due to the hazards of open circuit CT’s, the Current terminal block is equipped with a special hood that includes top and bottom retaining screws. It is required that this terminal block be fully assembled includ-ing the hood in order to properly secure the current terminal block. Failure to fully assemble and secure this connector to the meter chassis can result in an open circuit CT condition. NOTE: Because the hooded connector will cover the wiring designations printed on the block terminal, it is important to mark the wires so they can be identified after the ends are seated in the connec-tor housing.The Power Xpert Meter PXM4000/PXM6000/PXM8000 is equipped with multiple cards and terminal blocks. Each terminal block has an identification and each terminal has an identification. For example, the voltage input terminal block is identified as [VT-] The individual terminals are identified as V1, V2, V3, V4, and VR. The intended terminal identification scheme combines these references. For example, the V1 con-nection on the VT terminal block would be referred to as VT-V1. Proper use of this terminal block and terminal point nomenclature should result in a clear identification sheme for each connection to the meter.The current and voltage terminal blocks provided will accept up to one #10 AWG wire per connection. Before wiring and assembling connectors, wire markers should be placed on the wires a suf-ficient distance from the stripped ends to be clearly visible after the connector hoods are assembled. Each wire identifi-cation should be visually confirmed as it is attached to the terminal block.

VX Auxiliary Voltage Terminal Block Inputs

VT Voltage Terminal Block Inputs

CT Current Terminal Block Inputs


3 Installation

Wiring of CT & VT Connections, Con’t.Check to be sure all required CT and VT terminal block and terminal block hood hardware is available. Do not proceed with installation without the correct CT and VT terminal block and terminal block hood hardware.Insulation should be stripped back 3/8 in. for proper connection. A 1/8 in. flat blade screwdriver should be used to tighten the terminal block screws.Current and Voltage terminal block hoods are equipped with retaining brackets to retain the wires in the proper wire channel. To prevent accidental damage to wire insulation while assembling connector hoods, retaining brackets be securely and properly installed.The hooded connector, when properly assembled, can be grasped to insert and remove from terminal block socket. Do not remove terminal blocks by pulling on the wires. Terminal blocks are polarized and should only be inserted in the proper orientation. To prevent damage to the equipment or hazardous conditions, care should be taken to orient the terminal plug correctly with respect to the socket before insertion.If CT or VT terminal blocks or connector hoods are lost or damaged, contact your Eaton representative to obtain the correct replacement hardware. WARNING! The use of improper CT or VT teminal block hardware may result in severe injury or death. Photos of the Power Xpert Meter with hooded connections properly installed are displayed on the following page.


3 Installation

3.7. CT & VT Connector Installation on the Power Xpert

VT and VX Voltage Terminal Block hood as-semblies

CT Terminal Block hood as-sembly

Wire markers

CT Terminal Block Retaining Screws

NOTE: Because the hood-ed connectors will cover the wiring designations printed on the block terminals, it is important to mark the wires so they can be identified after the ends are seated in the connector housings.


3 Installation

3.8. MeterDimensions


3 Installation

Dimension, Con’t.


3 Installation

3.9. WIRING

Wiring of the Power Xpert Meter must follow a suitable wiring plan drawing. The phase wiring plan refers to the drawings made for the specific application. It describes all electrical connections between the meter and external equipment. A network wiring diagram can also be helpful for networked systems. Specific wiring diagrams are useful when creating the overall wiring plan drawing. Wiring diagrams for each system configura-tion are addressed below. WARNINGSSHOCK HAZARDS:

IF THIS DEVICE IS BEING USED ON A SINGLE PHASE SYSTEM, WIRE TO PHASE A AND NEUTRAL.

The following general considerations should be complied with during the wiring of the Power Xpert Meter. All wiring must conform to applicable Federal, State and Local codes.The wires to the terminal blocks must not be larger than AWG No. 10 (CT, VT, VX). Larger wire will not connect properly to the terminal block. Wiring diagrams contacts are shown in their de-energized position.Because the Power Xpert Meter monitors the neutral-to-ground voltage, the chassis of the meter must be connected to ground. A good low impedance ground is essential for proper functioning.

PT AND CT SECONDARY CIRCUITS ARE CAPABLE OF GENERATING DANGEROUS VOLTAGES AND CURRENTS WITH THEIR PRIMARY CIRCUITS ENERGIZED, AND COULD CAUSE PERSONAL INJURY AND OR DEATH.

The proper selection of any required current transformers or potential transformers is criti-cal to the proper and accurate functioning of the Power Xpert Meter. Instrumentation grade devices are required. Shorting blocks for CTs and a three-phase switch or circuit breaker for voltage are recommended near the equipment for ease of installation. If assistance with the selection process is desired, contact Power Quality Technical Support representative.

3.10. FusesIt is required that user supplied fuses be installed as described below. External fuses should be installed in the meter voltage tap to the main lines, near the meter housing. 600 V 1/2 A BUSS type KTK-R-1/2 Fast Acting or equivalent fuses are recommended for the Power Xpert Meter VT connections. External fuses should be installed in the potential transformer lines as specified in the National Electric Code for the specific application. The power supply wiring should be fused or put on a breaker sized to protect the wire.

3.11. Hipot and Megohm (Megger) Testing

CAUTION

DO NOT HIPOT OR MEGOHM TEST THE METER. SEVERE DAMAGE TO THE METER CAN RESULT.


3 Installation

3.12. Communication Wiring

The Power Xpert Meter (PXM 4000/6000/8000) has inverted terminal blocks for CM4 - the 24V Auxiliary I/O Power and CM6 - the Display Power. These inverted terminal blocks prevent the user from crossing 24v source and communication terminals.RS485 fail safe biasing resistors are used at each master port.Eaton strongly recommends using ferrules on wire ends when connecting to a terminal block. When connecting to a terminal block, the twisted pair sensitivity is critical for COM0, COM1 and COM2. This means that the Data A wire must match up with Data A on the terminal and the Data B wire must match up with Data B on the terminal.

**RS485 maximum cable length is dictated by baud rate. Above 38.4Kbaud the length is restricted to 2,000 ft.

Terminal Port Name Port Type

Port Connection

Cable Length Cable Type Max Baud Rate

Max Number of Devices

End of Line Termination

Star Tap Twisted Pair Sensitivity

CM5 COM0 Dis-play RS485

Terminal Plug 2,000ft / 610 M

ShieldedTwist-edPair 115 K 16 120ohms NO NO YES

CM3 COM1RS485 RS485 Terminal Plug

**4,000ft / 1,219.20 M


CE3 COM2RS485 RS485 Terminal Plug

**4,000ft / 1,219.20 M


CE4 COM3RS232 RS232 DB9 50 ft / 15 M ShieldedCable 115 K 2(1:1) na NO NO YES

CE1 LAN/WAN 100Fx ST 400 M Multimode62.5 m 100M 2(1:1) na NO NO NO

CE2 LAN/WAN 10/100 T RJ45 328 - 492 ft/100-150M

CAT5 Shielded TwistedPair / UTP* 100M 2(1:1) na NO NO NO

CM1Local Con-figuration 10/100 T RJ45 98 ft / 30 M

CAT5 Shielded TwistedPair / UTP 100M 2(1:1) na NO NO NO


3 Installation

3.13. RS485 Network

The following simplified rules apply to a given system consisting of master and slave de-vices. For more complex configurations please refer to standard wiring specification rules for the RS485 network.

The maximum system capacity is 4,000 feet of communication cable and 32 devices. Make sure the twisted pair wire is recommended for RS485 network use. For reference, review the RS485 wiring spec for wiring specifications. Tie the communication cable shield to ground only once at the RS485 master device.

3.14. RS485 Cable Characteristics

Make sure the twisted pair wire is recommended for RS485 applications:• Single twisted pair for data 18-24AWG• Shield consiting of aluminized Mylar & partial coverage braid with drain wire• Characteristic impedance ~ 120 ohms• Data L-L capacitance ~12pF/ft.• Typical ratings are 75C and 300V NEC CM• Belden Data Tray series 3074F is 600V NEC TC

3.15. RS485 Wiring Basics

The maximum system capacity is 4000 ft. of cable and 32 devices. The baud rate can restrict the maximum cable length (see the table on pg. 3-14).

• Wiring is done in a strict daisy chain without taps or stars

• 120 ohm 1/4W end of Line Termination Resistors (EOLTR) are required at each end of the cable

• Attach like terminals to like terminal types for each RS485 port being net-worked.

• Tie the communication cable, shield to ground, at one location only.

• Data line definition - As per the RS485 standard - In an idle marked state (logic 1) Data B (+) will be electrically > than Data A (-)

Note: When connecting to third party RS485 devices their data line nomenclature may be inverted. If the RXD LED is on continuously, this indicates a crossed data pair.

• The use of ferrules to terminate the cable ends is strongly recommended to minimize problems with frayed wires and to strengthen the terminal block con-nection, when daisy chaining wires use a dual wire ferrule.

Phoenix Contact and many other vendors carry ferrules and crimping tools for this pur-pose.For more information about RS485 wiring, please refer to TD 17513, Eaton Electrical field Devices Communication Wiring Specification.

Fail safe Pull up/down Bias resistors (Rb) are used to insure that the RS485 link goes to a marked state when no node is driving the line. The bias resistors are applied at only the Master node of each RS485 link and not at each slave. The display is always a master


3 Installation

and has bias resistors installed. The COM ports on PXMCE and PXMCM cards have jumpers to selectively engage the bias.

• COM0 functions as a slave to the display - jumpers default to Rb NOT EN-GAGED.

• COM1 defaults to a slave - jumpers defaults to Rb NOT ENGAGED

• COM2 defaults to a master - jumpers default to a Rb ENGAGED

Refer to Appendix F for jumper placement on the PXCE card. Refer to Appendix E for jumper placement on the PXCM card.


3 Installation


3 Installation

3.16. LEDs

The Power Xpert Meter contains several LEDs for health, application event status and communication links. These LEDs provide a quick way of confirming power, application status (event) and communication activities.

Meter LEDs

The Health LED, located on the bottom left side of the meter, will blink green at a slow rate (1 sec on/off) when the meter has no fault conditions present. It will blink red at an accelerated rate (twice per second) when a reboot operation is required due to a self-test failure, an internal fault, an invalid configuration, or a communication fault during power- up initialization. NOTE: During initialization, the Status LED will blink red in patterns of 3 until the meter’s Digital Signal Processor (DSP) is running and accumulating energy. At that point, the Health LED will blink green rapidly while the Power Xpert Meter’s Linux operting system boots. NOTE: For NOTE: For the first minute, the Health LED will blink green rapidly. During this time, the Power Xpert Meter accumulates energy, but does not record new min/max values. It will blink red rapidly to indicate that changes to settings will not take effect until the meter is rebooted. If the Health LED is off continuously, this indicates the power is off or an abnormal condition exists. If the Health LED is on continuously, this indicates an abnormal condition. The Status LED, located on the bottom left side of the meter (next to the Health LED), will be either green or red. Normally be solidly green, but will slowly blink red when there are unacknowledged events in the Power Xpert Meter’s Events list. After the events are acknowledged or cleared, the Status LED will return to a solid, green state. If the LED re-peats a series of three red blinks, the meter is in factory test mode. See the Troubleshoot-ing chapter for more information.

Card LEDs

The blue Power LED, (located in the center of the PXMPS-1 faceplate, is lit whenever power is applied to the meter. Before servicing the meter, ensure that this LED is not lit.The following ports have transmitting LEDs and receiving LEDs that blink when transmit-ting or receiving information respectively:

• LAN/WAN 10/100 T RJ45 (CE2) • COM2 RS485 (CE3)• COM3 RS232 (CE4)• COM3 Modem (CE5)• Local Configuration 10/100 T RJ45 (CM1)• COM1 RS485 (CM3) • COM0 Display (CM5)

The Ethernet ports support a link LED and combine the TXRX function as a bicolor LED. The PXMIO Card has an S1 LED at the bottom of the card that follows the status of solid state relay #1. This red LED can be used with optical standards.

Display LEDs

The Green Health LED located on the Display unit will respond as stated above for every meter connected to the display regardless of how many meters are connected, one or sixteen. The Green Health LED on the face of the meter is only reporting the health of that specific meter unit.


3 Installation

The Red Event LED on the Display unit will turn on when an event is triggered. When the user acknowledges all the triggered output events from all the meters connected to the display, the Red Event LED will turn off. NOTE: The Health and Event LEDs on the Display unit report on every meter connected to the display.

3.17. Display Link Addressing

The Power Xpert Base Meter has a rotary Base Address switch (meter address) located on the bottom left side of the meter. This rotary switch is used for addressing the display link and acts as both the user input and a simple indicator. All other communication links, except the local con-figuration port which is locked at 192.168.1.1, will be configured in the setpoint section of the user interface.This Base Address switch is for the Display Port (COM0) only and is not to be used for any other communication port (COM1, COM2 or COM3).

3.18. Java JRE PC Installation

Prior to accessing the Power Xpert Meter from your PC, you must download the latest version of Java J2SE JRE (Java Runtime Environment). To do this, follow the steps below.1) Visit site http://java.sun.com/.2) Click on Downloads from the left side of the screen. 3) Select the latest version of J2SE from the drop down list under Java 2 Platform, Standard Edition (J2SE) and click on GO.4) Click on Download JRE from the list.5) Select the appropriate download based on your operating system. 6) Download and install the Java JRE.

3.19. Comm Reset

You can reset all of the communications ports by pressing a recessed button located to the left of the status LEDs. The button is marked “Com Reset.” This may be done as part of troubleshooting. The button must be held for at least 2 seconds to prevent pressing it accidentally.


3 Installation


4 Introduction to Web Server Screens

4 INTRODUCTION TO WEB SERVER SCREENS

This chapter is an introduction to the Power Xpert Meter web server main screens and describes how to access basic information through them. Each option provides easy access to basic metering functions as well as setup configuration. Other information, such as waveforms, trending graphs, harmonic tables, phasors and ITIC curves is also available. The Functions on the Web Server Screens chapter provides more detailed information about the functions, features and options available on each screen.



4.1. Home, Meter, Power, Quality, Energy, I/O, Events & Setup Screens

HOME SCREEN (DEFAULT)

The Home Screen displays an overview. From this screen the user can gain additional information about Meter, Power, Quality, I/O, Energy, Events and Setup. These selectable options are displayed in a menu bar at the top of the screen, as illustrated below in figure 1. When one of the options is selected, the main section of the screen will update to display information about that option.Each screen provides the means to access more detailed information by clicking on text that is highlighted or underlined. For example, in the Quality section of the home screen below, the phrases, Latest 10 Min and Latest 24 Hrs, are underlined. By clicking on these options, the user will be able to access information that occurred during those time frames.NOTE: The setup screens require a password to edit settings.

THE METER HOME SCREEN

OptionsClick on a button in the menu bar to access a new main screen specific to that selection.

Highlighted/un-derlined text in various locations on the screens can be selected for more information about that topic.

When a Meter Option is selected (Power, Quality, Energy, etc.), the main section of the screen updates accordingly to display information about that selection. On the updated screens, further selections can be made to view more detailed information.

Current screen selection

Events Indicator The indicator will blink if an event is occurring while a meter is monitored.

Date/Time Navigation to optional slave Power Xpert Meter



JAVA JRE

If the screen below is displayed instead of the Home Screen, it may mean that Java Runtime Environment (JRE) is not installed on your machine. Click on the link in the text at the bottom of the screen to install the required software. After the JRE is installed, open a new browser window to start the Power Xpert web interface.

METER UPGRADE LINK

On the Home Screen of PXM4000 meters, you can upgrade the meter to a PXM6000 series meter by clicking the Click here to upgrade link. This link will open the PXM4000 to PXM6000 upgrade page on the Eaton web site. You can read more about upgradinig from a PXM4000 to a PXM6000 in Section 10.13.



4.2. The Meter Main Screen

The left side of the Meter, Power, Quality and Energy screens contain selection options available with some statistics. Drop down menus and radio buttons allow the user to select the information to be viewed and options for viewing it. For example, the Meter screen below has a dropdown menu that allows the user to select how the voltage is viewed; Line to Line, Line to Neutral or Symmetric. It also contains radio buttons that permit the user to select the voltage view; Average, AB, BC, CA or NG. When a selection is made, the screen will update to display the information selected. This is a “snapshot” of the current values plus the historical values in the designated range (zoom). It doesn’t update automatically. Reselect the information to update the the display.In the upper central portion of the screens, another drop down menu provides options for graphi-cally viewing the information as well as print and save buttons. For example, on the Meter screen the user can select Phasor, Waveform, or Harmonics views. To pan, zoom or view the graph in full screen, click one of the options below the graph. The zoom feature provides the following options:

• (Zoom1) 16-hour range of 5-minute data pans to 48 hours • (Zoom2) 48-hour range of 15-minute data pans to 192 hours (8 days)• (Zoom3) 8-day range of 1-hour data pans to 28 days• (Zoom4) 64-day range of 8-hour data pans to 56 weeks• (Zoom5) 1,344-day (192-week) range of 1-week data pans to 44 months

The Print Icon But-tonClick on the Print icon button to access a printer in order to print the graph displayed on the screen. This is avail-able for the Energy, Trend, Waveform and Harmonic dis-plays.

The Save ButtonClick on the Save button to open a browser window in order to save the information in the selected zoom level as a .csv file. This is available for the Energy, Trend, Waveform and Har-monic displays.

The Print ButtonThis Print button provides a “print screen” function. Use this button to capture a graphic of the entire screen.

Zoom Use the plus and minus keys and zoom value to zoom in and out.

The following saves .xls data wth the Save Table button

The following saves .csv data wth the Save button



4.3. The Power Main Screen

The left side of the Meter, Power, Quality and Energy screens contain selection options available with some statistics. Drop down menus and ra-dio buttons allow the user to select the information to be viewed and options for viewing it.In the upper central portion of the screens, another drop down menu provides options for graphically viewing the information.

4.4. The Quality Main Screen



4.5. The Energy Main Screen

Click on the TOU drop-down box, then click on the option desired to navigate to that screen. The options are: De-mand Profile, Demand Comparison, Energy Profile and Energy Comparison.

The Events ScreenThe left side of the screen lists events and the event log (e.g.; per-son logged in, new min/max, etc.) for the device. Click on an event to view detailed information about that event.Drop down menus near the top of the screeen provide viewing options such as Captured Pa-rameters or Waveform. To pan, zoom or view graphs in full screen, click on one of the op-tions below the graph. From this box, you can navigate to a waveform view or single event ITIC plot. The RMS plot to the right shows the RMS voltage trend line of the wave-form captured during the disturbance.



4.6. Selecting Other Devices From The Events Screen

The Event screen can be used to view events that have occurred on devices that are monitored by the Power Xpert Meter. Click on Select Other Device under the Active Events heading. The Device Selector Screen, that lists the devices that are connected to the meter, will appear. Active events will be indicated beside the device’s name. Click on a device to view detailed information about the event.

4.7. Setup and I/O Screens

The left side of the Setup screens contain expandable tree structures that list all of the screens available for viewing or configuration as displayed below. Click on one of the selections to view detailed information. An EDIT button will appear to enable the editing of information on the screen. NOTE: Edit functions require a user name and password. When EDIT is selected, dropdown boxes, check boxes, radio buttons and/or text boxes will appear to provide option selection. NOTE: If an invalid entry is attempted, a pop up box will appear displaying an error message. Verify parameters and enter a valid entry.



The I/O screen

(Future Option)

4.8. I/O Screen

On Power Xpert Meters equipped with a PXMIO card, the I/O screen displays the status of the Discrete Inputs and Relay Outputs. For selected Discrete Inputs that are configured as counters, a profile plot appears. Typically, these represent consumption of Water, Air, Gas, Electricity or Steam from flow other than metering devices.


5 Introduction to the Local Graphical Display

Turn to Highlight

BACK

Push to Select Hold in for Help

EventsHealthPower Xpert

5 INTRODUCTION TO THE LOCAL GRAPHICAL DISPLAY

This chapter is an introduction to the Power Xpert Meter local display screens and describes how to access basic information through them. Each option provides easy access to basic metering functions as well as setup configuration. Other information, such as waveforms, trending graphs, harmonic tables, phasors, and ITIC curves is also available. Chapter 7, Functions on the Graphical Display Screens, provides more detailed information about the functions, features and options available on each screen. The Power Xpert Meter Graphical Display contains: • Power Quality LED• Events LED• Back Button• Navigator• 10/100 Ethernet Port

NavigatorTurn to select (highlight) options on the screen. While high-lighted, Push the Navigator to select the currently highlighted function.

10/100 Ethernet Port (for local display network)

The Events LEDreflects the events status for the meter to which the display pointed, and serves the same function as the meter’s Status LED.

The Events LED will blink when there are unacknowledged events on the meter. Acknowl-edging or or clearing the events returns the LED to an unlit state.

If the Events LED is in a repeating pattern of three blinks followed by a long pause, then the meter is in “factory test mode.” Factory test mode has DS 1 & 2 on and the meter should never be operated with this setting. To correct this, see the Trouble-shooting chapter.

The Health LED displays on/off status; blinks slowly during normal use as health LED.

Back ButtonPush in to return to the previously viewed screen.



5.1. The Main Screens

The five main screens in the Power Xpert Meter system are displayed below and on the following page. By rotating the Navigator on the front of the Power Xpert Meter, you can move from screen to screen and from topic to topic within each screen. Underlined text on each screen provides access to further information about the selected topic. Navigating from screen to screen and topic to topic is more fully explained on the following pages.

MeterNine

Meter Power Quality Events Setup

Avg. LL Voltage:

481.2 VAvg. Current:

176 A Frequency:

59.97 Hz View By Phase:

A B CAUXVLL VLN IA IB IC

481.2 277.2 0.176 0.175 0.176

The Meter Main Screen

MeterNine

S 145 kVA

P 130 kW

Q - 64 kvar

(View Profile)


Energy:

93624 kWh

Demand: 134 kW

Lag

Min Max

LeadPF--

The Power Main Screen

MeterNine

%TDD -- 1.58%

THDV -- 1.43%

KF 5.18

CF 1.71

Flkr 0.000

% 9’s10 Mins


24 Hours

rt

Caution

Normal

The Quality Main screen

MeterNine


ITIC Curve

20 EventsHave occurred and not been addressedLatest Event: Wed, 28 Dec 2005 15:02:59 EST Transient Triggered (View Events...) (Silence Buzzer...)

The Events Main Screen

11 TriggersAre currently enabledand not monitoring the System(View Trigger Items...)

2,953 Log Items...and old Events are be-ing stored for historical analysis



5.2. Navigating from one Main Screen to another

The Meter, Power, Quality, Events and Setup screens are listed in a menu at the bottom of all screens in the system.

Turning the Navigator will move the double arrow above the names of each screen in the menu.

1. Place the double arrow above the name of the screen you wish to view.

2. Press the Navigator to display the selected screen.

3. When the new screen is displayed, the white triangular marker at the bottom of the menu bar will move to mark the new selection.

In summary;The double arrow is used to navigate to a new screen selection. The triangular marker acts as a tab to mark the main screen currently in use.

5.3. The Back Button

The Back Button on the front of the PowerXpert module is used to return to previous screens. Press the Back Button to go back to the previously viewed screen.

MeterNine


View Setup

Edit Setup

Login Logout

The Setup Main Screen






5.4. Accessing Details From All Main Screens

Detailed information can be accessed from each main screen by selecting underlined topics with the Navigator.

• Turn the Navigator until an item of interest is high-lighted.

• The double arrow selection tool will disappear from the screen menu when the selected text is highlighted.

• Press the Navigator to view information about the selected topic. The screen will update to display the information requested.

Press the Back button on the PowerXpert Meter front plate to return to one or more previous screen selections.

NOTE: This manual does not display every screen available in the PowerXpert system. The graph-ics and accompanying text are intended to be used as a basic guide for research into the topic of the user’s choice.

5.5. The Meter Main Screen

Turn the Navigator to highlight an option; press the Navigator to select. Detailed information is available on several layers of additional screens that can be accessed from the screens displayed below. Select underlined text options to “drill-down” to these screens.Press the Back button on the Power Xpert Meter front plate to return to one or more previous screen selections.

MeterNine


Avg. LL Voltage:


176 A Frequency:


A B CAUX VLL VLN IA IB IC

481.2 277.2 176 175 176

The Meter main screen



L-L L-N Symmetric

Summary AUX Voltage Line to LineVavg: 481.2 V VAB: 481.3 VVBC: 481.2 VVCA: 481.1 V

Summary Phase a

VAB: 481.3 V IA: 176 AVAN: 277.3 V IФ: -26o

VФ: 0o

Phase A Phase B Phase C

Summary Phase b

VBC: 481.2 V IB: 175 AVBN: 277.2 V IФ: -146o

VФ: -120.1o


Sum-mary Phase c

VCA: 481.1 V IC: 176 AVCN: 277.1Ф: 95o


Summary Voltage Line to Line

Vavg: 481.2 V VGN: 0.9 VVAB: 481.3 VVBC: 481.2 VVCA: 481.1 V

L-L L-N Symmetric

Summary Measured Current

lavg: 176 A I Ground: 0.IA IA 176 A I Neutral: 20.2 A IC: 175 A IC: 176 A

Measured Symmetric

Min/Max Frequency Chan-nel

Present 59.97 Hz Min: 59.96 Hz Tue, 24 Jan 17:11:36 EST

Max: 60.04 Hz Tue, 24 Jan 17:11:36 EST

Min/Max Trend Trig-

MeterNine


Avg. LL Voltage:


176 A Frequency:


A B CAUX VLL VLN IA IB IC

481.2 277.2 176 175 176


ADDING AND MODIFYING DATA

You will be required to enter data on screens; for example, during trigger set up and configura-tion. Data is entered one character at a time by rotating and pressing the Navigator. When “Edit” is highlighted and the Navigator is pressed, the field can be edited. Simply turn the Navigator to cycle through entry choices then press the Navigator to select one. If information is already entered into a field and modification is necessary, simply turn the Naviga-tor to the desired value and press the Navigator to select. Press “Delete” to remove the right-most character. When done modifying the field, select “OK”.



5.1. The Power Main Screen

Turn the Navigator to highlight an option; press the Navigator to select. Detailed information is available “drilling down” through layers of additional screens. Select underlined text options to ac-cess these screens.Use/press the Back button on the PowerXpert Meter front plate to return to one or more previous screen selections.

Summary Apparent Power

System: 145 kVA A: 49 kVA B: 48 kVA C: 48 kVA

S P Q

Summary Real Power

System: 130 kW A: 44 kW B: 43 kW C: 43 kW

S P Q

Profiles

126 kAh 93624 kWh 104026 kVAh 45343 kVArh Reset Profile...

Summary Present Demand

175 A 134 W 149 VA Reset Demand (15 minute win-

Present Last

Summary Energy Present

93624 kWh 104026 kVAh 45343 kVArh RESET

Present Last Summary Displacement PF

System: .89 A: .89 B: .89 C: .89

Displacement Apparent

Summary Reac-tive Power

System: 64 kVars A: 22 kVars B: 21 kVars C: 21 kVars

S P Q

MeterNine

S 145 kVA

P 130 kW

Q - 64 kvar

(View Profile)


Energy:

93624 kWh

Demand: 134 kW

Lag

Min Max

LeadPF--

The Power main screen

5.2. The Quality Main Screen

Turn the Navigator to highlight an option; press the Navigator to select. Detailed information is available on several layers of additional screens that can be accessed from the screens shown in the following figure. Select underlined text options to access these screens.Use/press the Back button on the Power Xpert Meter front plate to return to one or more previous screen selections.



9’s of Availability Previous Month: 100.00% Month To Date: 100.00%

Flicker Perceptibility 0.821 Pst: 0.751 Plt: 0.524

Summary PQ Index 10 Minutes

Level: Value:SAGS: 0.00 0.00SWELLS: 0.00 0.00dv/dt: 0.00 0.00TDDi: 0.00% 0.00THDv: 0.00% 0.00Flicker: 0.00 0.00

PQ Index 10 Min PQ Index

6 sigma:

3 sigma:

Mean:

Summary K Factor Max: 5.86 A: 5.24 B: 5.86 C: 5.58

Summary Crest Factor Max: 1.76 A: 1.41 B: 1.41 C: 1.76

Summary THD Current

Max: 25 A IA: 14 A Harm Wave IB: 25 A Harm Wave IC: 19 A Harm Wave

THDi A

Summary THD Line to Line Percent

Max: 1.43% VAB: 1.36% Harm Wave VBC: 1.43% Harm Wave VCA: 1.20% Harm Wave

L-L % L-LV L-N% L-NV AUX L-L% AUX

Alert if > 300

Caution if > 200

Normal at 100

MeterNine

%TDD -- 1.58%

THDV -- 1.43%

KF 5.18

CF 1.71

Flkr 0.000

% 9’s10 Mins


24 Hours

Alert

Caution

Normal

The Quality main screen

Summary PQ Index 24 Hours

Level: Value:SAGS: 1.00 100SWELLS: 0.00 0.00dv/dt: 0.00 0.00TDDi: 1.58% 62.7THDv: 1.43% 57.0Flicker: .751 150Total: 150

PQ Index 10 Min PQ Index

5.3. The Events Main Screen

Turn the Navigator to highlight an option; press the Navigator to select. Detailed information is available on several layers of additional screens that can be accessed from the screens shown in the following figure. Select underlined text options to access these screens.Use/press the Back button on the Power Xpert Meter front plate to return to one or more previous screen selections.



MeterNine


ITIC Curve


The Events main screen



Silence Buzzer ???

(No screen comes up when selected on Pow-erXpert unit.)

Trigger List

Exit Trigger ListiTIC: L1 SagsiTIC: L2 SagsiTIC: L4 SagsiTIC: L8 SagsiTIC: L1 SwellsiTIC: L2 SwellsFast Transient

Event List

Exit Event ListWed, 28 Dec 2005 15:02:59 EST Transient TriggeredWed, 26 Dec 2005 15:02:52 EST Transient TriggeredWed, 26 Dec 2005 15:02:44 EST Transient TriggeredWed, 26 Dec 2005 15:02:35 EST Transient TriggeredWed, 26 Dec 2005 15:02:28 EST Transient Triggered

! = Event Still Activex = Event Ack’d Ack All Events (Reset All Events...)

Log List

Exit Log ListWed, 25 Jan 2006 09:51:35 EST New Min (Fundamental Vbc A)...Wed, 25 Jan 2006 06:33:13 EST New Max (Even Harmonic In)...Wed, 25 Jan 2006 06:33:13 EST New Max (Even Harmonic Ic)...Wed, 25 Jan 2006 05:39:53 EST New Max (Fundamental In)=Wed, 25 Jan 2006 05:39:53 EST New Max (Fundamental Ic)=0

(Reset All Logs...)

200

150

50

100

01 1 ms 10 sec

Volta

ge (%

nom

inal

)

Sag/Swell Duration

15 Tran-sient

Pass 3Fail 5

The meter can be setup to monitor events, such as low frequency, out of limit voltage, etc., by set-ting up triggers. When activated, these triggers can sound a buzzer or send an e-mail. From the Events main screen, detailed information about selected events in the Events List can be reviewed. The Events List displays the time of the event and the kind of event that occurred. An ex-clamation point in front of an event means the event is still active. A check mark in front of an event means that it has been acknowledged. Using the Navigator, highlight and select the event in question.Additionally, the user can select, View Captured Parameters, View Trigger For the Event or View Present Measurement. The View Captured Parameters link can be used to view waveforms, harmonic values, metered values or the harmonic spectrum at the time of the event. The View Trigger link shows the trigger that was tripped and the cause of the event. The View Present Measurement link shows the present measurements. For example: if the trigger is an Out Of Limit Current, the screen will show the Current Screen.

5.4. The Setup Main Screen

Turn the Navigator to highlight an option; press the Navigator to select. Detailed information is available on several layers of additional screens that can be accessed from the screens displayed below. Select underlined text options to access these screens.Use/press the Back button on the Power Xpert Meter front plate to return to one or more previ-ous screen selections. Refer to the Setup chapter for more detailed information about the Setup screens.



Note: For ease of use, the Power Xpert Meter is shipped with several preconfigured UserID/Password sets. The “X” UserID with the “X” password are most convenient for use the local display. For higher levels of security, these defualts should be changed.

Quick Setup...

View & Create Triggers...

Meter Setup & Commissioning...

Setup This Display...

OK Cancel

OK Cancel

MeterNine


View Setup

Edit Setup

Login Logout

The Setup main screen


6 Functions on the Web Server Pages

6 FUNCTIONS ON THE WEB SERVER PAGES

OVERVIEW

The Power Xpert Meter provides a detailed web interface, providing information for six main func-tional categories: • Meter• Power• Quality• I/O• Events• Setup A great deal of information is nested in drop down menus and related pages within these catego-ries. By drilling-down through the many pages within each category, increasing levels of detail about the measurements can be obtained. This chapter of the manual is not an exhaustive resource that displays every page in the system. The intent is to give the user a general understanding of where the most useful and pertinent infor-mation is stored for review.All of the stored, measured values can be accessed by using any communication port available, including the display (unless otherwise noted). NOTE: Setup information is not provided in this chapter. See Setup on the Web Pages, for setup details.

A GENERAL NOTE ABOUT GRAPHS AND PLOTS

When you display a trend plot or other graph on the various meter pages, this is a “snapshot” show-ing the last values when the graph was displayed plus the historical data. To update with more cur-rent values, reselect the value that’s displayed in the list of radio buttons along the left of the page.

METER

The Meter page(s) provide Voltage, Current, and Frequency readings. You can view information by measurement type or by phase. By Accessing further details you can look at trends, min/max values, and set triggers. By right-clicking on any page, a drop-down list appears that you can use to reset data, as shown to the left.

VOLTAGE

The Power Xpert Meter measures line-to-line and line-to-neutral voltages and calculates rms values over the period of 200 milliseconds. The system average values are calculated for main voltage channels as well as AUX. NOTE: Systems with an AUX (PXM42xx) option will provide only line-to-line voltages.Symmetric components are available for main voltage channels; symmetric components are not available for PXM40xx and PXM42xx versions of the meter. The Power Xpert Meter maintains a log of all voltage rms measurements over the period of 1 year with date and time stamps. This information is also available as a trend for display and communica-tions. The min, max and averages are recorded for each interval; 2 days at 5 minute intervals, 28 days at 1 hour intervals and 44 months at 1 week intervals. The most recent minimum and maximum values are detected for all the voltage channels and sym-metric, and are logged with date and time stamps. Current minimum and maximum values can be cleared by the user at any time. After the current values are cleared, the meter will begin calculating new minimum and maximum values.



LOCATING VOLTAGE INFORMATION

From the Meter Home Page select Line to Line, Line to Neutral, Symmetric or AUX Line to Line from the drop-down box beside Voltage on the left side of the page. Click one of the radio buttons below Voltage to select a specific voltage (e.g.: AB, BC, CA, NG, AN, BN, or CN). The page will update to display the selection.You can select trending, waveform, harmonics or phasor graphs from the drop-down box near the top of the page.When Trend and Min/Max is selected, the minimum and maximum values are displayed with date and time stamps.When Harmonics is selected, a table is displayed showing the Voltage, Voltage Angle, Current, Current Angle and the calculated watts (V x I x COS[Angle V - Angle I]). Note: Watts calculation is only valid for AN, BN, and CN selections.By default, the fundamental frequency is displayed. It can be excluded by clearing the Exclude Fundamental check box on the left side of the page.



CURRENT

The Power Xpert Meter measures per phase and average system current and calculates rms val-ues over the period of 200 milliseconds. Neutral and Ground current measurements are optional; if the current transformer for neutral or ground is not available the user has an option to select the calculated values for ground and neutral currents. NOTE: Current measurements are not available for the Vaux channels. Symmetric components are available for all channels, but are not available for the standard PXM40xx version of the Power Xpert Meter. The meter will maintain a log of all rms measurements and symmetric components over the period of 1 year with date and time stamps. The same information is available as a trend for display and communications. The most recent minimum and maximum values are detected for all the channels and symmetric, and are logged with date and time stamps. Current minimum and maximum values can be cleared by the user at any time. After the current values are cleared, the meter will start calculating new minimum and maximum values.



LOCATING CURRENT INFORMATION

From the Meter Home Page, select RMS or Symmetric from the drop-down box beside Current. Click one of the radio buttons listed below Current to select a specific phase; neutral or ground. The page will update to display the selection.To view the trending, waveform, harmonics or phasor graphs, click the drop-down box located on the top right side of the page and make a selection. When Trend and Min/Max is selected, the minimum and maximum values are displayed on the bot-tom, right side of the page with date and time stamps.When Harmonics is selected, a table is displayed showing the Voltage, Voltage Angle, Current, Current Angle and the calculated watts (V x I x COS[Angle V - Angle I]). By default, all the options are selected when the Phasor diagram is selected. You can clear an op-tion on the left side of the page to remove the correlating point of the phasor diagram.



FREQUENCY

Frequency measurements for the meter occur every 200 milliseconds using phase A voltage on V1. In the absence of voltage, there is no frequency measurement. The result is a gap in the trend data for frequency-dependent items. For the same reason, 0 Hz is never recorded as a minimum value. A trend of frequency measurements is maintained with date and time stamps. Minimum and maximum values are detected and saved with date and time stamps of the occurrence.

LOCATING FREQUENCY INFORMATION ON THE WEB

From the Meter Home Page, click the frequency radio button beside Frequency on the left side of the page. To view the trending, and phasor graphs, click the drop-down box at the top of the page and make a selection. When Trend and Min/Max is selected, the minimum and maximum values are displayed on the bot-tom right side of the page with date and time stamps.By default, all the options are selected when the Phasor diagram is selected. The user can unselect an option on the left side of the page to remove the correlating point of the phasor diagram.



POWER

The Power and Energy section contains information about the present power consumption in the following categories: Demand, Energy, Load Profile and Power Factor. The meter calculates the following instantaneous values averaged over a period of 200 milliseconds:• Apparent and Displacement Power Factor for System, Phase A, Phase B and Phase C• Apparent Power for System, Phase A, Phase B and Phase C• Real Power for System, Phase A, Phase B and Phase C• Reactive Power for System, Phase A, Phase B and Phase C

The meter will log the trend for all of the above measurements, as well as detect and save Mini-mum and Maximum values with date and time stamps for all of the above parameters.

LOCATING APPARENT & DISPLACEMENT POWER FACTOR, REAL POWER, REACTIVE POWER AND APPARENT POWER FOR SYSTEM INFORMATION ON THE WEB

From the Power Main Page, click the drop-down box beside PWR Factor. Select Apparent or Displacement. Click one of the radio buttons on the left side of the page that represents the kind of Power Factor you want to view. The page will up date to display a graph with minimum, maximum and average values as per the selection.



DEMAND

Demand is the power consumption at the receiving terminal averaged over a specific interval of time or in response to a signal at a designated discrete input. The Power Xpert Meter is capable of measuring demand by two internally triggered methods; Fixed or Sliding in intervals of 1 to 60 minutes. These measurements are configured to calculate the Total Current, kW Forward/Reverse, Net and Sum; kVar Lead/Lag, Net and Sum and kVA.

FIXED AND SLIDING DEMAND

Fixed demand (Total Current), which is an average system current over time can be set to average current over a range of 1 to 60 minutes. This is known as a fixed window. For example, setting the current demand window to 15 sets the meter to determine the average current over the past 15 minutes and update the value every 15 minutes. Power demand can be fixed, as described above, or sliding. For example, a 15 minute average can be obtained that is updated every 3 minutes. To accomplish this, the subinterval is set to 3 minutes and the number of intervals is set to 5 (i.e. 3 minutes times 5 intervals equals 15 minutes). NOTE: The demand interval is the number of minutes in the average calculation. The subinterval is the number of minutes between updates. Separate demand values are computed on a monthly basis. At the end of every calendar month, peak demand values with date and time stamps are saved as last months values. Peak demand is reset and new peak demand calculations begin for next month. In the absence of an External Synchronization, the Power Xpert Meter starts demand windows according to the real-time clock at the top of the hour and top of the minute. In the typical case of a 15-minute window, the intervals would start at the top of the hour, at 15 minutes past the hour, half-past the hour, and 45 minutes past the hour.Demand reset can be executed using any available user interface or it can be scheduled in the calendar. When the demand reset occurs a snapshot of all peak demand values and energy values are saved as last demand reset values and demand reset count, with date and time.Snapshots of peak demand values with date and time stamps and energy values are saved in a file each time the demand reset is executed. This self-read process can also be initiated by using the calendar schedule. The latest five snapshots are available in a file.



EXTERNAL SYNC

You can also designate any of the discrete inputs as an external synchronization source for setting when the meter should record a demand update. You can set a discrete input to be an sync source through Setup > Meter Setup & Commissioning > I/O > Internal I/O > Inputs page.

REAL-TIME PRICING

In addition to the above, the meter also computes separate demand values for Real-Time Pricing (RTP). RTP can be activated by discrete input #8 to the meter when configured. The meter deter-mines the peak demand for individual rate periods and saves the information with the date and time of the occurrence. Present demand and previous demand values are made available along with peak demand data, over any available communication port and display.

TIME OF USE

The Power Xpert Meter also supports four rate periods for Time Of Use (TOU): A, B, C, and D in addition to displaying RTP. The Demand information also contains the current value for Today’s Peak Demand

LOCATING DEMAND AND ENERGY INFORMATION ON THE WEB

From the Energy Main Page, • Click a radio button on the left side of the page that represents the kind of Energy and Demand

you wish to view. • From the drop-down box near the top of the page, select either TOU, Demand Profile, Demand

Comparison, Energy Profile, or Energy Comparison. • Select to view the Present or Last Reset information from the second drop-down box. The page will update to display the information selected.



While viewing either the Demand Comparison or Energy Comparison pages, you can also select to compare the information to previous time periods: day-to-day (Demand Comparison only), week-to-week, or month-to-month. If you’re comparing two specified time periods, such as two different days, a calendar control appears when you click either date. Click a day in the calendar to select the beginning and ending dates in the comparison. The < and > controls in the calendar move forward or backward one month. The << and >> controls move the calendar forward or backward one year.

Placing your mouse over any point on the energy plots reports both the timestamp and energy that’s represented at that point.

The table shown below the graph shows each demand update value along with the time stamp. The contents of the table can be written to file formats that are compatible with various third-party spreadsheet, database, and data analysis tools. The Save button writes a comma separated val-ues (.csv) file, with the data from the table, to the My Documents folder of your local computer. The first row in the file contains the column titles. The Save Table button saves the same data to your local computer, but in Excel format (.xls). If you want to just copy a section of a table to paste into a report or email, simply select the infor-mation you want in the table and copy it to the Windows clipboard (Ctrl+C). Place the cursor where you wish to paste the information in the third-party application and press Ctrl+V. To select the entire table, press Ctrl+A



ENERGY

The Power Xpert Meter measures and accumulates three kinds of energy values every 200 mil-liseconds, Real Power (Watts), Reactive Power (vars) and Apparent Power (VA). With four different types of accumulation; forward, reverse, net and sum for Real Power and Reactive Power. These measurements are configured to calculation the kWh Forward/Reverse, Net and Sum; kvarh Lag/Lead, Net and Sum and kVAh. Real Power (Watts). Note: Watts calculated is only valid for AN, BN, and CN selections. Reactive Power (var) You can select the means of calculating vars is in the QuickSetup page. By default, reactive power is calculated from VA and Watts as sqrt(VA^2 - W^2). As a result, harmonic power is included with vars. Optionally, reactive power is calculated via a 90-degree phase shift of the fundamental. As a result, harmonic power is typically excluded from the vars. and is the product of the voltage, the current, and the sine of the phase angle between them. Apparent Power (VA) is the square root of the sum of the squares of the active and reactive pow-ers. Separate energy registers accumulate energy values over a period of one calendar month. At the end of every calendar month, energy values along with peak demand values with date and time stamps are saved as last months values. At this point energy accumulators are reset and begin ac-cumulating values for next month.

TIME OF USE

The meter supports four rate periods for Time Of Use (TOU): A, B, C and D in addition to total rate, which is independent of time of use. Energy values are accumulated separately for each of these rate periods. The Time of Use page also display the Present, Peak, and Peak Today (the peak value for this day) Demand.

DEMAND PROFILE

Demand Profile is the magnitude and duration of loads applied in a prescribed time sequence, including the transient and steady-state characteristics of the individual loads. The Power Xpert Me-ter logs demand profile data from the following sources: • kWh/kw: Forward, Reverse, Net, Sum, • kVAh/kVA - kVARh/kVAR: Received,Delivered, Net, Sum, and Total Current in Amperes.



You can set the interval (in lengths of 5 to 60 minutes), sub-interval (used if Sliding is selected), and the demand type (Fixed, Sliding, or Ext_Sync) in the Demand page under Setup . The interval dura-tion for the monthly profile is a fixed interval of 15 minutes, it is not user programmable. The interval duration for the yearly profile is a fixed interval of 1 week and is not user programmable.

LOCATING DEMAND PROFILE INFORMATION ON THE WEB

On the Energy Main Page, click the kind of Profile you wish to view. Select Demand Profile from the drop-down box.

Point Timestamp W

1 September 30, 2010 11:00 AM -0400 7384.91016

2 September 30, 2010 12:00 PM -0400 7621.14990

3 September 30, 2010 01:00 PM -0400 8742.00000

4 September 30, 2010 02:00 PM -0400 7764.87012

5 September 30, 2010 03:00 PM -0400 7768.47998

6 September 30, 2010 04:00 PM -0400 7699.20020

7 September 30, 2010 05:00 PM -0400 8325.04980

8 September 30, 2010 06:00 PM -0400 6712.81982

9 September 30, 2010 07:00 PM -0400 3861.97998

10 September 30, 2010 08:00 PM -0400 4162.10010

11 September 30, 2010 09:00 PM -0400 2675.40991

12 September 30, 2010 10:00 PM -0400 2324.07007

13 September 30, 2010 11:00 PM -0400 2107.26001

14 October 01, 2010 12:00 AM -0400 2136.13989

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DEMAND COMPARISON

The Demand Comparison page is similar to the Demand Profile page, but provides a graph you can use to compare two overlaid demand plots from selectable periods of time. You can select to compare plots between:• Today with Yesteday• This Week with Last Week• This Month with Last Month• 2 different Days• 2 different Weeks• 2 different MonthsPeak demand is shown in the graph as a dashed line.

LOCATING DEMAND COMPARISON INFORMATION ON THE WEB

On the Energy Main Page, click the kind of Profile you wish to view. Select Demand Comparison from the drop-down box.



Point Timestamp W Timestamp W

1 October 08, 2010 12:00 AM -0400 1926.56006 October 07, 2010 12:00 AM -0400 2939.25000







N/AN/A

To:To:

10/07/201010/08/2010Today with Yesterday

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ENERGY PROFILE

Again, the Energy Profile page is similar to the Load Profile, with all of the same options, but dis-plays the daily energies from midnight to midnight. To locate this page, select Energy Profile from the drop-down box.

Point Timestamp Wh

1 August 05, 2010 12:00 AM -0400 118050.00000

2 August 06, 2010 12:00 AM -0400 100662.00000

3 August 07, 2010 12:00 AM -0400 49797.69922

4 August 08, 2010 12:00 AM -0400 51260.89844

5 August 09, 2010 12:00 AM -0400 130211.00000

6 August 10, 2010 12:00 AM -0400 122054.00000

7 August 11, 2010 12:00 AM -0400 127460.00000

8 August 12, 2010 12:00 AM -0400 115361.00000

9 August 13, 2010 12:00 AM -0400 96440.50000

10 August 14, 2010 12:00 AM -0400 43476.80078

11 August 15, 2010 12:00 AM -0400 43526.80078

12 August 16, 2010 12:00 AM -0400 118971.00000

13 August 17, 2010 12:00 AM -0400 111533.00000

14 August 18, 2010 12:00 AM -0400 128842.00000

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Energy ComparisonThe Energy Comparison page shows the same information as the Energy Profile, but allows you to compare data as follows:• This Week with Last Week• This Month with Last Month• 2 different Weeks• 2 different MonthsTo locate this page, select Energy Comparison from the drop-down box.

Point Timestamp Wh Timestamp Wh

1 August 01, 2010 12:00 AM -0400 48620.69922 August 29, 2010 12:00 AM -0400 43385.19922



4 August 04, 2010 12:00 AM -0400 120393.00000 September 01, 2010 12:00 AM -0400 138424.00000




09/29/201009/01/2010

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QUALITY

The Quality section of the Power Xpert Meter outlines the measurements that have been calculated and describes the health of the system. It consists of seven main sections of information, THD Cur-rent, THD Voltage, K Factor, Crest Factor, Flicker and 9’s of Availability.

THD

The Total Harmonic Distortions (THD) is the ratio, expressed as a percent, of the rms value of the ac signal after the fundamental component is removed and inter-harmonic components are ignored, to the rms value of the fundamental. The formula for THD is provided below. The variables X1 and xn may represent either voltage or current and may be expressed either as rms or peak values, as long as all are expressed in the same fashion. X1 = fundamental value of current or voltage.xn = nth harmonic value of current or voltage.

CURRENT

The THD Current is calculated for peak phase A, B and, C as Amperes. Meanwhile, the TDD% is calculated as a percentage of peak demand current. The THD Current is individually measured for Odd, Even and Inter Harmonics. Maximum THD Current is determined using individual phase THD Currents. All of the THD Current measurements in the Power Xpert Meter are trended and mini-mum and maximum values are logged with date and time stamps.



Locating THD Current Information on the Web

From the Quality Main Page, click the top drop-down box beside THD Current to view informa-tion in Amperes or Percentage TDD. Click the second drop-down box to view Total, Odd, Even or Interharmonic information. The values listed under the drop-down boxes will update to reflect the selections. The user can then click one of the radio buttons to view graphical information about Max, Phase A, Phase B, Phase C or Neutral. The graph will update accordingly. Using the drop-down box above the graph, the user can select to view this information as a waveform, trend with minimum and maximum values or harmonics.

THD VOLTAGE

The THD Voltage is calculated for line-to-line and line-to-neutral as a percentage as well as in volts. The THD Voltage is individually measured for Odd, Even and Interharmonics. The Maximum THD Voltages for line-to-line and line-to-neutral is also determined. The Power Xpert Meter Vaux (PXM 4200/6200/8200) option will also contain line-to-line THD Volt-age calculations for phases AB, BC and CA as a percentage as well as in volts. The Maximum THD Voltage value will be determined from the individual line-to-line values. All of the THD Voltage measurements are trended and minimum and maximum values are logged with date and time of each occurrence.

Locating THD Voltage Information on the Web

From the Quality Main Page click the drop-down box next to THD Voltage on the left hand side of the page to select to view Line to Line Voltage, Line to Line %, Line to Neutral Voltage, Line to Neu-tral %, Vaux Line to Line Voltage or Vaux Line to Line % information. When this option is selected, click the second drop-down box to select to view Total, Odd, Even or Interharmonic information. The values listed underneath the drop-down boxes will change to reflect the selections. At this point the user can click one of the radio buttons to view graphical information for either Max, AB, BC or CA. Once this radio button is selected the graph shown on the right hand side of the page will change. Using the drop-down box above the graph, the user can select to view this information as a waveform, trend with minimum and maximum values or harmonics. NOTE: Vaux Line to Line Voltage and Vaux Line to Line % are only options on the meter Vaux ver-sion.

K FACTOR

The meter calculates the Maximum, Phase A, Phase B and Phase C values for K Factor. The K Factor is a derating factor related to the sum of the squares of harmonic current times the squares of their harmonic numbers (multiples of the fundamental).

HOW TO LOCATE K FACTOR INFORMATION ON THE WEB

From the Quality Main Page the K Factor values are listed half way down the left hand side of the page.

CREST FACTOR

The meter calculates the Maximum, IA, IB and IC values for Crest Factor. The Crest Factor is the ratio of peak current to rms current. A pure sine wave has a crest factor of 1.414.

LOCATING CREST FACTOR INFORMATION ON THE WEB

From the Quality Main Page the Crest Factor values are listed towards the bottom half of the left hand side of the page.

FLICKER

Per EN61000-4-15, Flicker is a variation of input voltage, either magnitude or frequency, sufficient in duration to allow visual observation of a change in electric light source intensity. The Power Xpert Meter provides Perceptibility, Pst (10 minutes), Plt (2 hours), Trend and Trigger information for Flicker line-to-line and line-to-neutral values. (Flicker available on the 6000 and 8000 Series).



LOCATING FLICKER INFORMATION ON THE WEB

From the Quality Main Page, click one of the radio buttons listed underneath “Flicker” on the bottom left side to view Perceptibility, Pst or Plt graphical information. The graph will update to display the selection.

9’S OF AVAILABILITY (PERFORMANCE OR COMPLIANCE)

The availability of service is often measured in how many 9’s of availability it provides. If the service is up 90% of the time, it has one 9 of availability. If service is up 99% of the time, it has two 9’s of availability, and so on. These 9’s translate into how much downtime is allowed per year. • 90.0000% = 37 days• 99.0000% = 3.7 days• 99.9000% = 8.8 hours• 99.9900% = 53 minutes• 99.9990% = 5.3 minutes• 99.9999% = 32 secondsThe Power Xpert Meter is highly configurable for 9’s of Compliance. Any or all of the Out of Limits triggers can be selected in the 9s calculation.The meter calculates the Previous Month’s 9’s of Availability percentage and the current Month To Date’s 9’s of Availability percentage.

LOCATING 9’S OF AVAILABILITY INFORMATION ON THE WEB

From the Quality Main Page the 9’s of Availability values are listed at the bottom of the left hand side of the page.

PQ INDEX

The Power Xpert Meter calculates power quality information (in graphical and text format) for the last 10 minutes and the last 24 hours; providing the level and value of Sags, Swells, dv/dt, TDD, THDv and Flicker. The 10 minute value is the worst of the PQ components. The Alert level is for values 300 and higher while caution values are above 200. A value below 200 is normal. The 24 hour value ratchets up to new 10 minute PQ values and decays with a 17 hour time constant.

LOCATING PQ INDEX INFORMATION ON THE WEB

From the Home Page the PQ Index graph is located on the top right hand side of the page. Click one of the underlined options, Latest 10 Minutes or Latest 24 Hours to view detailed information about the selection. Once the option is selected the top right hand side of the page will change list-ing the levels and values. At this point the user can either view the alternate option, or return back to the Power Quality Index by clicking on the underlined label.

EVENTS

The Power Xpert TM Meter monitors and logs six kinds of Events; Input Status, Out of Limits, De-mand Overload, ITIC Sag/Swell, Sub-cycle Distrubance and Transients. Each event can be used to trigger parameter capture, waveform capture and/or send e-mail as well as be used to change the state of internal or external I/Os.

TRIGGERS

The following list highlights potential triggers. Each event trigger can be automatic or manual depending on the selection of the user. In the case of auto trigger, the limits of the next trigger are calculated by the meter based on the historical data; in the absence of historical data default values are used. In manual triggering the meter will use the programmed limits set by the user. Each trigger input can be programmed to monitor performance as for 9’s of Availability or Com-pliance, capture waveform, capture parameters and/or send e-mail. Once an event is triggered, the Reset value will be used to check and clear the condition. Every event and it’s corresponding parameters along with the date and time of the occurrence are logged and available for display or retrieval using a communication port. (Triggers are available on the 6000 and 8000 Series).



OUT OF LIMITS

The Power Xpert Meter monitors and logs Out of Limit events for the following triggers:• System Voltage Swells and Sags • Line to Line Voltage Swells and Sags • Line to Neutral Voltage Swells and Sags • AUX Line to Line Voltage Swells and Sags • Voltage Symmetric components V0, V1 and V2• Voltage Unbalance• Over Current on all current inputs• Current Symmetric Components I0, I1 and I2• Current Unbalance• Real Power (System and Individual Phase Upper and Lower Limits)• Reactive Power (System and Individual Phase Upper and Lower Limits)• Apparent Power (System and Individual Phase Upper and Lower Limits)• Apparent Power Factor (System and Individual Phase Upper and Lower Limits)• Displacement Power Factor (System and Individual Phase Upper and Lower Limits)• System Upper THD Voltage (for Total)• Line to Line Upper THD Voltage (for Total)• Line to Line Upper TD Current (for Total)• Line to Neutral Upper THD Voltage (for Total• System Lower THD Voltage (for Total)• Line to Line Lower THD Voltage (for Total)• Line to Neutral Lower THD Voltage (for Total)• System Upper Flicker Perceptibility • Line to Line Upper Flicker Perceptibility• Line to Neutral Upper Flicker Perceptibility

DEMAND OVERLOAD

The Power Xpert Meter can shed load upon demand amperes, demand watts, demand reverse watts, demand vars capacitive load, demand vars inductive load or demand VA. Each Demand Overload selection has a threshold as if it were a trigger threshold. The meter can only change state on demand window boundaries. For example, with a 15-minute fixed window, the meter can only change state every 15 minutes.

ITIC CURVE (Available on the 6000 and 8000 Series). )

Information Technology Industry Council update of what was known as the CBEMA Curve. This classifies sag and swell events according to their magnitude and duration. The Power XpertTM Meter classifies these further with a severity rating (L1, L2, L4, L8). A number of Out of Limits trig-gers are unavailable on the 4000 series. Voltage Symmetric components V0, V1 and V2, Voltage Unbalance, Current Symmetric components, I0, I1, I2, Current Unbalance, and Flicker Perceptibility (Available on the 6000 and 8000 Series).

FAST TRANSIENT (Available on the 8000 Series).

A transient is the rapid change in voltage. A typical transient reaches its peak in 5us and lasts 50us. The meter captures transients with optional hardware that samples 5 channels at up to 6Msp for 22ms or 1 Msps for 131 ms.



SUBCYCLE DISTURBANCE

A disturbance is the rapid change in voltage with a duration that can be as long as 1/4 cycle. The meter captures disturbances as events, which records all voltage and current channels at 30.72 ksps for 1000 ms.

LOCATING EVENTS ON THE WEB

From the Events Main Page the user can view all events that have occurred and a log that displays event date and time. Click a specific event in the log to display the detailed information on the page. Use the drop-down box at the top of the page to view the captured parameter or waveform. Click the ITIC Curve button on the bottom of the page to view the ITIC Curve. (Available on the 6000 and 8000 Series). From this new page the user can click any event listed on the ITIC Curve to display the Event page listing the event information relevant to the event selected.

Note: Using your left mouse button, you can pull the divider to the right to resize the window frames and expose the entire Event and Event Log descriptions. You can also view the view the ITIC Curve for a single ITIC event.To view a single ITIC event:1. Select an ITIC event in the Events frame. 2. Click the drop-down list box near the top of the page.



3. Select ITIC curve.Note: You can also use the drop-down list to navigate to a waveform view or a timeline view. The ITIC single event view places an event icon crosshair onto the plot in a location that corre-sponds to the magnitude and duration of the ITIC event. The user can quickly classify an ITIC event as a potentially disruptive event if the crosshair icon (shown to the left) is outside the bold black lines in the orange, red, or gray colored zones of the plot (L2, L4, L8).

This is the ITIC disturbance waveform that was captured with the ITIC single event view displayed on the previous page.

In this example, the ITIC event was captured and added to the summary page counters. The wave-form was configured to capture, resulting a waveform view. The single event ITIC analysis page displays the event details and where the event falls onto the ITIC plot.

EVENT CALENDAR AND TIMELINE VIEWS

You can also view the last 500 recorded events on either a monthly calendar or on a timeline view. These views make it much easier to locate events over a period of time. When you switch from the calendar to the timeline view, you can “zoom” in to smaller time units. To view the Calendar:• From the Events page, click the Events Timeline button. The following figure shows a typical Events Calendar and details its controls (refer to the keyed explanation that follows the figure). (Available on the 6000 and 8000 Series).

jUse the Filter control to select which event types are displayed in the Events Calendar and the Update button to display only those event types selected in the filter. If an event occurs on a given day, that day is shown in that event type’s color. If multiple event types occur on a given day, the day is shown in red (as in this example). by default, all event types are selected. Clearing a check box also clears those types from the the Events Calendar.



kClick this button to return to the Events page.

lClick this control to pan the Calendar to the previous month.

mClick this control to pan the Calendar to the next month.

nThese days are shown in color, meaning that events occurred on these days. Red signifies multiple event types occurred (see the Filter control for the event type color codes). Clicking a day “drills-down” to the timeline view so that you can see what events occurred during the day.

The default view of the Events Timeline view shows the day’s events on an hour-by-hour basis; however, you can expand the time scale resolution down to hundredths of a second.

USING THE EVENTS TIMELINE

The following figure details the controls on the Events Timeline page. Refer to the keys following the figure for a description of the various controls. The Events Timeline page is divided into an event timeline in the top half and a waveform timeline or captured parameters display in the bottom half. If you select an event in the top timeline, its data is displayed in the lower half of the page.



jClick this button to return to the Event page.

kUse the Filter control to select which event types are displayed in the events timeline (top half of the page). Clearing a check box also clears those types from the the Timeline View. When you have made your filter selections, click the Update button to update the event timeline.

lClick an Event to show its Waveform or Captured Parameters in the lower half of the page. The currently selected event is shown in red and its associated trigger point(s) are shown as red vertical lines in the waveform timeline. Events appear “stacked” in the event timeline when they occur close together in time; however, you can change the resolution of the timeline us-ing the Zoom control to “spread them out.” Hovering the mouse pointer over a single event displays its information.

If the trigger for another event also appears in a waveform timeline, that event is shown in yellow in the events timeline and its trigger point(s) are shown as yellow horizontal lines in the waveform timeline (see the following figure).



mThe Pan slider moves the events timeline forward (right) or backward (left) through time.

nThe Zoom control changes the resolution of the events timeline. Click the center drop-down list and select one of the following time resolutions:7 Switches the page to the Events Calendar view.6 Timeline displays 14 hours in two-hour increments.5 Timeline displays nine hours in one-hour increments.4 Timeline displays 75 minutes in 15-minute increments.3 Timeline displays 75 seconds in 15-second increments.2 Timeline displays 2.5 seconds in 0.5 second increments.1 Timeline displays 0.1 seconds in 0.025 second increments.The + and - buttons beside the drop-down list either increase or decrease the timeline resolu-tion one setting from the current value.

oIf there are more events than can be shown in the events timeline through the current Pan and Zoom controls, then the Meter creates up to 10 Events Timeline pages. You can switch between these by either selecting a page from the drop-down list or clicking the << (previous page) or >> (next page) buttons.

pThe Previous and Next buttons shift the waveform timeline to view the next trigger point related to the currently selected event. If there is only one trigger point within the event, these buttons remain deselected.

qIf there is both Waveform and Captured Parameter data available for the event, click this but-ton to switch between these views.

rUse this drop-down list (shown to the left) to select from the available data to display in the waveform timeline..

sThe Pan and Zoom controls work similarly to the ones in the events timeline. Pan moves the waveform timeline forward and backward in time while the zoom controls increase or decrease the resolution. Note that you can also choose to print a waveform timeline (print button) or save the waveform values to a comma-separated values file (file button) on your local com-puter.


7 Functions on the Graphical Display

7 FUNCTIONS ON THE GRAPHICAL DISPLAY

7.1. Overview

The Power Xpert Meter is divided into six main functional categories: • Meter• Power• Quality• I/O• Events

• Setup

A large amount of information is nested in drop down menus and related screens within these cat-egories. By accessing the many screens within each category, increasing levels of detail about the measurements can be obtained. This section of the manual is not an exhaustive resource that displays every screen in the system. The intent is to give the user a general understanding of where the most useful and pertinent infor-mation is stored for review.

NOTE: Setup information is not provided in this chapter. See the Setup chapter.



7.2. Meter

The Meter screen(s) provide the user with Voltage, Current and Frequency readings. It allows the user to view information by measurement type or by phase. Further details, such as trends, min/max values and set triggers can also be reviewed.

VOLTAGE

The Power Xpert Meter measures line to line and line to neutral voltages and calculates rms values over the period of 200 milliseconds. The system average values are calculated for main voltage channels as well as Vaux. NOTE: Systems with a Vaux option will provide only line to line voltages.Symmetric components are available for main voltage channels; symmetric components are not available for Basic and Vaux versions of the meter. The Power Xpert Meter maintains a running log of all voltage rms measurements over the period of 1 year with date and time stamps. This information is also available as a trend for display and communications. The min, max and averages are recorded for each interval; 2 days at 5 minute intervals, 31 days at 1 hour intervals and 12 months at 1 week intervals. The most recent minimum and maximum values are detected for all the voltage channels and sym-metric, and are logged with date and time stamps. Current minimum and maximum values can be cleared by the user at any time. When the current values are cleared, the meter will begin calculat-ing new minimum and maximum values.

LOCATING VOLTAGE INFORMATION

From the Meter Home Screen, highlight and select an underlined voltage option. A detailed voltage screen will appear. Highlight and select the kind of voltage (Line to Line, Line to Neutral, Symmetric Components or Vaux) you wish to view. The screen will update to display the selected information. The user can access more details, such as minimum and maximum values, trending, phasors, triggers, waveforms or harmonics via under-lined text options.

The Line to Neutral Voltage Screen

MeterNineAvg. LL Voltage:

0.176 A Frequency:


480.2 V Avg. Current:

277.3 V

277.2 V

277.2 V

0.9 V



LOCATING INFORMATION ABOUT CURRENT

From the Meter Home Screen, highlight and select the underlined current from the right side of the screen. The screen will update to display the selected current (Measured or Symmetric Compo-nents). Additional detailed information can be selected from any underlined item such as minimum and maximum values, trending, triggers, harmonics or waveforms.

176 A Frequency:




Summary Measured Current

lavg: 176 A I Ground: 0.1 A IA: 176 A I Neutral: 20.2 A IB: 175 A Demand: IC: 176 A 177 A

Measured Symmetric MeterNine




LOCATING FREQUENCY INFORMATION

From the Meter Home Screen, highlight and select the underlined frequency from the right side of the screen. A detailed frequency screen will appear. Highlight and select the kind of information (Minimum and Maximum, Trend or Trigger) you wish to view. The screen will update to display the selection. Select Channel in the drop down menu to view screens that display Phasor, Harmonic and Waveform information.



0.0 VAvg. Current: 176 A Frequency:

59.97 Hz

Min/Max Frequency

Present: 59.97 Hz Min: 59.97 Hz Tue, 24 Jan 2005 7:11:32 EST

Max: 60.04 Hz Tue, 24 Jan 2005 7:11:32 EST

(Reset all Min/Max)

Min/Max Trend Triggers MeterNine


Channel

• Phasor• Harmonic• Waveform

Channel

Avg V VAN VBN VCN VAB VBC VCA VNG



Locating Apparent & Displacement Power Factor, Real Power, Reactive Power and Apparent Power information

From the Power Main Screen, highlight and select the underlined PF (Power Factor) value, S (Ap-parent Power) value, P (Real Power) value or Q (Reactive Power) value. The screen will update to display new information each time a new option is selected. From these screens, additional details can be viewed via the underlined text options. For example, if PF is selected on the main Power screen, the screen will update to make Displace-ment or Apparent information information available. Highlight and select the phase you wish to view to access another screen containing that information. In like manner, additional details about trend and trigger information are also available.

Lead

Lag

Quality

MeterNine

S 145 kVA

P 130 kW

Q - 64 kvarEnergy: 93624 kWh

Lag

Min Max

LeadPF:

Events Setup

MeterNine Displacement Appar-

Summary Displacement PF

System: .89 Lag

A: .89 .89 Lag

B: .89 Lag

C: .89 Lag

Events Setup

MeterNine


Min/MaxPhase A Displacement PF

Present: .89 Lag

Min: .74 Tue, 24 Jan 2005 7:11:32 EST

Max: 0.99 Tue, 24 Jan 2005 7:11:32 EST

Min/Max Trend Triggers

-

(Reset all Min/Max)




DEMAND

Demand is the power consumption at the receiving terminal averaged over a specific interval of time. The Power Xpert Meter is capable of measuring demand by three methods; Fixed, Sliding and Thermal, in intervals of 1 to 60 minutes. These measurements are configured to calculate the Total Current, kW Forward, kW Reverse, kW Net, kW Sum, kvar Lead, kvar Lag, kvar Net, kvar Sum and kVA.

FIXED, POWER AND SLIDING DEMAND

Fixed demand (Total Current), which is an average system current over time can be set to average current over a range of 1 to 60 minutes. This is known as a fixed window. For example, setting the current demand window to 15 sets the Power Xpert Meter to determine the average current over the past 15 minutes and update the value every 15 minutes. Power demand can be fixed, like described above, or sliding. For example, a 15 minute average can be obtained that is updated every 3 minutes. To accomplish this, the subinterval is set to 3 min-utes and the number of intervals is set to 5 (i.e. 3 minutes times 5 intervals equals 15 minutes). NOTE: The demand interval is the number of minutes in the average calculation. The subinterval is the number of minutes between updates. Separate demand values are computed on a monthly basis. At the end of every calendar month, peak demand values with date and time stamps are saved as last months values. Peak demand is reset and new peak demand calculations begin for next month. Demand reset can be executed using any available user interface or it can be scheduled in the calendar. When the demand reset occurs a snapshot of all peak demand values and energy values are saved as last demand reset values and demand reset count, with date and time.Snapshots of peak demand values with date and time stamps and energy values are saved in a file each time the demand reset is executed. This self-read process can also be initiated by using the calendar schedule. The latest five snapshots are available in a file.

Real-time Pricing

In addition to the above, the Power Xpert Meter also computes separate demand values for Real-Time Pricing (RTP). RTP can be activated by one of the discrete inputs to the meter when config-ured. The meter determines the peak demand for individual rate periods and saves the information with the date and time of the occurrence. Present demand and previous demand values are made available along with peak demand data, over any available communication port and display.

Time Of Use (TOU)

The Power Xpert Meter also supports four rate periods for Time Of Use (TOU): A, B, C and D in ad-dition to total rate which is independent of time of use.



MeterNine

S 145 kVA

P 130 kW

Min Max

LeadPF:

LOCATING DEMAND INFORMATION

From the Power Main Screen, highlight and select the underlined demand value. The screen will update to display demand details. Highlight and select the kind of information (Present or Last Reset) you want to view. From the next updated screen, detailed information about each kind of value, Demand A, Demand kW, Demand kVA, Demand kvar or Reset is available. Depending on this selection, additional op-tions may be available. For example, from the Demand kW screen and Demand kVar screens, detailed information about Totals, Rate A, Rate B, Rate C, Rate D or RTP can be viewed.


Present Last Reset

Summary Present Demand

175 A 134 kW 149 kVA 69 kvar Reset Demand

MeterNine

Lag

Energy:

93624 kWh

Demand: 134 kW

MeterNine


Summary Total Peak Reactive Demand

Received: 69 kvar

Delivered: 1 kvar

Net: 68 kvar

Sum: 70 kvar

Total Rate A Rate B Rate C Rate



7.3. Energy

The Power Xpert Meter measures and accumulates Real Power (Watts), Reactive Power (Vars) and Apparent Power (VA) every 200 milliseconds. The means of accumulated four different kinds of accumulation; forward, reverse, net and sum for Real Power and Reactive Power. These measure-ments are configured to calculate the kWh Forward, kWh Reverse, kWh Net, kWh Sum, kvarh Lag, kvarh Lead, kvarh Net, kvarh Sum and kVAh. Real Power (Watts) is the square root of the sum of the instantaneous voltage mutliplied by current.

• Reactive Power (kvar) is the product of the voltage, the current and the sine of the phase angle between them.

• Apparent Power (kVA) is the square root of the sum of the squares of the active and reactive powers.

Separate energy registers accumulate energy values over a period of one calendar month. At the end of every month, energy and peak demand values with date and time stamps are saved as last months values. The energy accumulators then reset and begin accumulating values for next month.

Real-time Pricing

In addition to the above, Power Xpert Meter also computes separate energy values for Real-Time Pricing (RTP). RTP can be activated by any the discrete inputs to the meter when configured. The meter determines the energy consumed for individual rate periods and saves the information with the date and time of the occurrence. Present energy and previous energy values are made avail-able along with energy consumed data, over any available communication port and display.



Time Of Use (TOU)

The Power Xpert Meter supports four rate periods for Time Of Use (TOU); A, B, C and D, in addi-tion to total rate (E) that is independent of time of use. Energy values are accumulated separately for each of these rate periods.

LOCATING ENERGY INFORMATION

From the Power Main Screen, highlight and select the underlined energy value. The screen will update, displaying detailed energy information. Highlight and select the kind of information (Pres-ent or Last Reset) you wish to view. The screen will update again. From the new screen, detailed information about each kind of value; Energy kWh, Energy kVAh, Energy kVArh or Reset can be

accessed. Depending on the selection, additional options may be avail-able. For example, from the Energy kWh and Energy kVArh screens, more detailed information about Totals, Rate A, Rate B, Rate C, Rate D or RTP can be viewed.

MeterNine

S 145 kVA

P 130 kWLag

Min Max

Lead


PF: .89

Energy:

93624 kWh

Demand: 134 kW MeterNine MeterNine Present Last Reset

Summary Energy Present

43624 kWh

104026 kVAh

45343 kVArh

RESET MeterNine


Total Rate A Rate B Rate C Rate

Summary Reactive Energy Present

Received: 43624 kVArh

Delivered: 42 kVArh

Net: 45343 kVArh

Sum: 45427 kVArh



LOCATING LOAD PROFILE INFORMATION

From the Power Main Screen, highlight and select View Profile. The Profile screen will appear. Highlight and select the kind of Load Profile information you wish to view from the underlined op-tions. A new screen will appear displaying underlined kVAh, kWh, kVAh and kVArh options. When one of the options is selected, the screen will update to display a graph format. To view peaks from previous months and the current month, select Compare with Last Month. The screen will update to display a graph with this information The numbers represented in the graph can be viewed in list form by selecting Last Month or This Month from the bottom of the screen.

MeterNine

S 145 kVA

P 130 kW

Q -64 kVAr

Lag

Min Max

Lead


PF: .89

MeterNine

Energy:

93624 kWh

Demand: 134 kW

(View Profile) MeterNine

Profiles:

126 kAh

93624 kWh

104026 kVAh

45343 kVArh

Reset Profile... MeterNine


Profile Graph (Last Month Vs. This Month)

7.2

0.00Beg. Month End Month

Compare With Last Month

Last Month Peak: kVars

This Month Peak: kVars



7.4. Quality

The Quality section of the Power Xpert Meter outlines the measurements that have been calculated and describes the health of the system. It includes:

• TDD Current

• THD Voltage

• K Factor

• Crest Factor

• Flicker,

• 9’s of Availability(Compliance)

• PQ Index

%THD

The Total Harmonic Distortions (THD) is the ratio, expressed as a percent, of the rms value of the ac signal after the fundamental component is removed and inter-harmonic components are ignored, to the rms value of the fundamental. The formula for THD is provided below. The variables X1 and xn may represent voltage or current and may be expressed as rms or peak values, as long as all are expressed in the same fashion.

X1 = fundamental value of current or voltage.xn = nth harmonic value of current or voltage.

THD CURRENT AND %TDD CURRENT

The THD Current is calculated for phase A, B and C as Ampere; meanwhile, the %TDD is calcu-lated as a precentage of the peak demand current. The THD Current is individually measured for Odd, Even and Inter Harmonics. Maximum THD Current is determined using individual phase THD Currents. All of the THD Current measurements in the meter are trended. Minimum and maximum values are logged with date and time stamps.



Locating THD Current Information

From the Quality Main Screen, highlight and select the underlined THDI value. The screen will update to list detailed information about the THD Current. From this screen, additional options are available. Highlight and select the underlined values to view more detailed information. Information in Amperes or %TDD can be selected. Some values display icons that, when selected, will change the graphical format to a waveform or harmonic form.

MeterNine

%TDD -- 1.58%

THDV -- 1.43%

KF 5.18

CF 1.71

Flkr .752

% 9’s10 Mins


24 Hours

Alert

Caution

Normal


MeterNine

Summary IC Odd, Even, Int. Harmonics A

0 kAh

Odd: 26 A

Even: 3 A

Int. Harmonics 2 A

IA IB IC


MeterNineTDDi A

Summary TDD Current

0 kAh

Max: 25 A

IA: 14 A Harm Wave

IB: 25 A Harm Wave

IC: 19 A Harm Wave



Locating THD Voltage Information

From the Quality Main Screen, highlight and select the underlined THDV value. The screen will update to list detailed information about the THD Voltage. From this screen, additional informa-tion options are available. The user can select to view information about Line to Line Volts, Line to Line %, Line to Neutral Volts, Line to Neutral %, AUX Line to Line Volts or AUX Line to Line %. Some values display icons, that when selected, will change the graphical format to a waveform or harmonic form. Highlight and select the underlined values to view more detailed information about AB, BC or CA, minimum and maximum, trend and/or trigger information, etc.

NOTE: AUX Line to Line Voltage and AUX Line to Line % are only options on the Power Xpert Meter PXM 4200/6200/8200 series.

MeterNine

Summary CA Odd, Even, Int. Harmonics %

0 kAh

Odd: 1.36 %

Even: 0.1 %

Int. Harmonics: 0.0 %


AB BC CA

MeterNine

10 Mins 24 Hours

Alert

Caution

Normal


%TDD -- 1.58%

THDV -- 1.43%

KF 5.18

CF 1.71

Flkr .752

% 9’s

MeterNineL-L% L-LV L-N% L-NV IAUX L-L% AUX

Summary THD Line to Line Percent

0 kAh

Max: 1.43%

VAB 1.36% Harm Wave

VBC: 1.43% Harm Wave

VCA: 1.20 % Harm Wave



K FACTOR, CREST FACTOR, FLICKER & 9S OF AVAILABILITY

K FACTOR

The Power Xpert Meter calculates the Maximum, Phase A, Phase B and Phase C values for K Fac-tor. The K Factor is a derating factor related to the sum of the squares of harmonic current times the squares of their harmonic numbers (multiples of the fundamental).

LOCATING K FACTOR INFORMATION

From the Quality Main Screen, highlight and select the underlined K value to view a new screen listing all K Factor values.

Crest Factor

The Power Xpert Meter calculates the Maximum, IA, IB and IC values for Crest Factor. The Crest Factor is the ratio of peak current to rms current. A pure sine wave has a crest factor of 1.414.

MeterNine

%TDD -- 1.58%

THDV -- 1.43%

KF 5.18

CF 1.71

Flkr 0.000

% 9’s10 Mins


24 Hours

Alert

Caution

Normal

The Quality Main screen MeterNine

Summary K Factor 0 kAh Max: 5.72

A: 5.31

B: 5.70

C: 5.44


MeterNineSummary Crest Factor 0 kAh Max: 1.80

A: 1.77

B: 1.74

C: 1.73




FLICKER

Flicker is a variation of input voltage, either magnitude or frequency, sufficient in duration to allow visual observation of a change in electric light source intensity. The Power Xpert Meter provides Perceptibility, Pst (10 minutes), Plt (2 hours), Trend and Trigger information for Flicker line to line and line to neutral values. For definitions of Pst and Plt, see EN 601000-4-15. (Flicker is available on the 6000 and 8000 Series). LOCATING FLICKER INFORMATIONFrom the Quality Main Screen highlight and select the underlined FLKR value to view a new screen listing all Flicker values. The user can then highlight and select Perceptibility, Pst or Plt to view Line to Line and Line to Neutral detail. The user can also select to view this detailed information for either Perceptibility, Pst, Plt, Trend or Trigger.

LOCATING 9S OF AVAILABILITY INFORMATION

From the Quality Main Screen highlight and select the underlined %9s value to view a new screen listing percents from the previous month and the month to date.

MeterNine

%TDD -- 1.58%

THDV -- 1.43%

KF 5.18

CF 1.71

Flkr 0.000

% 9’s10 Mins


24 Hours

Alert

Caution

Normal


MeterNine


Flicker 0 kAh Perceptibility: 0.041

Pst: 0.198

Plt: 0.435

MeterNine

9s of Availability 0 kAh Previous Month: 100.000%

Month to Date: 100.000%




PQ INDEX

The PXM6000 and PXM8000 Power Xpert Meters calculate power quality information (in graphical and text format) for the last 10 minutes and the last 24 hours; providing the level and value of Sags, Swells, dv/dt, TDDI, THDv and Flicker.

LOCATING PQ INDEX INFORMATION

On the Quality Main Screen, highlight and select 10 Minutes or 24 Hours to view detailed informa-tion about the selection. The screen will update to display the levels and values in list form.

MeterNine

Summary PQ Index 10 Minutes Level PQ Value 0 kAh

SAGS: 0.00 0.00 Alert if > 300.00 SWELLS: 0.00 0.00 Caution if >200.00dv/dt: 0.00 0.00 Normal at >100.00 THDi: 0.56% 22.38THDv: 1.82% 72.66Flicker: 0.33 66.94Total: 72.91

PQ Index 10 Min PQ Index 24


MeterNine

%TDD -- 1.58%

THDV -- 1.43%

KF 5.18

CF 1.71

Flkr 0.000

% 9’s10 Mins


24 Hours

Alert

Caution

Normal




EVENTS

The Power Xpert Meter monitors and logs five types of Events, Out of Limit, Demand Overload, ITIC (sag/swell), Subcycle Distrubance and Fast Transients. Each event can be used to trigger parameter capture, waveform capture and/or send email as well as be used to change the state of internal or external I/Os.

TRIGGERS

The following list highlights potential triggers. Each event trigger can be automatic or manual depending on the selection of he user. In the case of auto trigger, the limits of the next trigger are calculated by the meter based on the historical data; in the absence of historical data default values are used. In manual triggering, the meter will use the programmed limits set by the user. Each trigger input can be programmed to monitor performance, capture waveform, capture param-eters and/or send e-mail. Once an event is triggered, the Reset value will be used to check and clear the condition. Every event and it’s corresponding parameters along with the date and time of the occurrence are logged and available for display or retrieval using a communication port.

OUT OF LIMITS

The Power Xpert Meter monitors and logs Out of Limit events for the following triggers:• System Voltage Swells and Sags • Line to Line Voltage Swells and Sags • Line to Neutral Voltage Swells and Sags • AUX Line to Line Voltage Swells and Sags • Voltage Symmetric components V0, V1 and V2• Voltage Unbalance• Over Current on all current inputs• Current Symmetric Components I0, I1 and I2• Current Unbalance• Real Power (System and Individual Phase Upper and Lower Limits)• Reactive Power (System and Individual Phase Upper and Lower Limits)• Apparent Power (System and Individual Phase Upper and Lower Limits)• Apparent Power Factor (System and Individual Phase Leading and Lagging Limits)• Displacement Power Factor (System and Individual Phase Leading and Lagging Limits)• System Upper THD Voltage (for Total)• Line to Line Upper THD Voltage (for Total)• Line to Line Upper THD Current (for Total)• Line to Neutral Upper THD Voltage (for Total)• System Lower THD Voltage (for Tota)• Line to Line Lower THD Voltage (for Total)• Line to Neutral Lower THD Voltage (for Total)• System Upper Flicker Perceptibility • Line to Line Upper Flicker Perceptibility• Line to Neutral Upper Flicker Perceptibility

DEMAND OVERLOAD

The Power Xpert Meter can shed load upon demand Amperes, demand Watts, demand reverse Watts, demand vars capacitive load, demand vars inductive load or demand VA. Each Demand Overload selection has a threshold as if it were a trigger threshold. The meter can only change state on demand window boundaries. For example, with a 15-minute fixed window, the meter can only change state every 15 minutes.

ITIC CURVE

Information Technology Industry Council update of what was known as the CBEMA Curve. This classifies sag and swell events according to their magnitude and duration. The Power XpertTM Meter classifies these further with a severity rating (L1, L2, L4, L8).



7.5. Fast Transient (Available on the 8000 Series).

A transient is the rapid change in voltage. A typical transient reaches its peak in 5µs and lasts 50µs. The meter captures transients with optional hardware that samples 5 channels at up to 6Msp for 22ms or 1 Msps for 131 ms.

7.6. Subcycle Disturbance

A disturbance is the rapid change in voltage with a duration that can be as long as 1/4 cycle. The meter captures disturbances as events, which records all voltage and current channels at 30.72 ksps for 1000 ms.

7.7. Locating Events

The Events Main Screen lists the number of Events, Triggers and Log Items. From this screen, the user can highlight and select View Events, View Triggers, View Log Items or ITIC Curve.

• When View Events is selected, the screen will update to list all date and time stamped events that have occurred. If an event is highlight and select from the list, a new screen will appear displaying detailed information about that event. Additional information can be accessed by highlighting and selecting View Captured Parameters, View Trigger or View Present Measurement.

MeterNine


ITIC Curve


The Events main screen



Silence Buzzer...

(No screen comes up when selected on Pow-erXpert unit.)

Trigger List

Exit Trigger ListiTIC: L1 SagsiTIC: L2 SagsiTIC: L4 SagsiTIC: L8 SagsiTIC: L1 SwellsiTIC: L2 SwellsFast Transient

Event List

Exit Event ListWed, 28 Dec 2005 15:02:59 EST Transient TriggeredWed, 26 Dec 2005 15:02:52 EST Transient TriggeredWed, 26 Dec 2005 15:02:44 EST Transient TriggeredWed, 26 Dec 2005 15:02:35 EST Transient TriggeredWed, 26 Dec 2005 15:02:28 EST Transient Triggered

! = Event Still Activex = Event Ack’d Ack All Events (Reset All Events...)

Log List

Exit Log ListWed, 25 Jan 2006 09:51:35 EST New Min (Fundamental Vbc A)...Wed, 25 Jan 2006 06:33:13 EST New Max (Even Harmonic In)...Wed, 25 Jan 2006 06:33:13 EST New Max (Even Harmonic Ic)...Wed, 25 Jan 2006 05:39:53 EST New Max (Fundamental In)=Wed, 25 Jan 2006 05:39:53 EST New Max (Fundamental Ic)=0

(Reset All Logs...)

200

150

50

100

01 1 ms 10 sec

Volta

ge (%

nom

inal

)

Sag/Swell Duration

15 Tran-sient

Pass 3Fail 5

PXM 6000 and PXM 8000



• When viewing captured parameters, the user can also view the information by Graphi-cal Waveform, Harmonic Values, Metered Values or Harmonic Spectrum. Highlight and select View Triggers to see each Trigger

• When View Log Items is selected, a new screen will appear that lists all logged event items. Highlight and select a specific event to view additional details about the item. To reset all of the logs, highlight and select Reset All Logs.

• When ITIC Curve is selected, the screen will update to display the ITIC Curve. Highlight and select any event listed on the ITIC Curve to display information about that event.


8 Setup on the Web Server Pages

8 SETUP ON THE WEB SERVER PAGES

8.1. Overview

This section provides information about Setup via the Web server, including the settings that are currently active and how to change settings in specific categories.

SETUP PAGES

When the Setup pages open, a collapsed tree structure is displayed on the left side of the page. Double-clicking topics within the structure will expand the list to include all the pages available for viewing or configuration. Click one of the options to view detailed information about the selection, as displayed below. The information will be displayed in the midsection of the page.List boxes, radio buttons, text boxes, etc., that are appropriate to the selection will appear to facili-tate editing.

NOTE: All configuration (edit) abilities discussed in the following sections require login with a user name and password to complete, as displayed below. The user account must have sufficient privileges to edit the page.After login, if the page remains idle for 10 minutes or longer, an automatic logout will occur with no visual confirmation that this has happened. If this occurs, the system will not respond to data entry attempts and you will have to login again to continue the editing process.NOTE: The user will be prompted with a pop-up message if an invalid entry is attempted.

SECURITY SETUP

You can use the security section to add/delete users, edit user names, change passwords, and change permissions. Account permissions is defined by the Security Group to which they are as-signed. The Security Groups range form high (1) to low (5) level security. The account’s security group must be equal to, or higher than, the group required to set security permissions in order to change security settings. For example, if the Security group permission is set to 2, then the account must have been assigned a group of 1 or 2 in order to change security settings. However, any user may change his or her own user account security settings without this permission.Security Setup has two pages; Users and Permissions. The Users section lists all users and their assigned Security Group. The user has the ability to:

• View all users and their Security Group• Edit the listing*• Remove the listing*• Set Password for the listing*• Add Users* With appropriate permissions

The Permissions page lists all setup pages and commands and the Security Groups required to edit them. Only users with the required Security Group or higher can edit that specific page. For example, if the Wiring Configuration page has a Security Group of 4, only users with a Security Group of 1 through 4 can edit that page. Only users with the required Security Group or higher as the Security Setup Permission page can edit the security levels for each page.



CancelOK

The following is a list of the pages that require a Security Group to be assigned:• Security • Clear Event Logs• Wiring Configuration • Clear Min Max • Triggers • Reset All Data • Meter Configuration (Demand/IP/TOU) • Reboot • I/O Configuration • Firmware Upgrade • Communication Port Setup • Set Date & Time• Demand Reset • Set Default Configuration• Energy Reset • Start & Stop Load Profile • Acknowledge Events • Clear Events and Waveforms • Acknowledge Event Logs

Locating Security Information On The Web

From the Setup Main Page, select Security from the tree structure. Click Users or Permissions Setup. If Users is selected, the page will list all the current users, with buttons to Edit, Remove, or Set Password. To add a user, click Add User at the top of the page and fill in the appropriate fields. After you is added, click Set Password to set the password of the new user. Click the Done button at the bottom of the page when entries are completed.



If Permissions Setup is selected, the page will list all of the setup types and commands that require a Security Group to be assigned. Each page listed will also have a security group number (1-5) assigned to it. You can change the security required to edit each page by clicking the drop down arrow next to the group number and selecting another security group.

NOTE: Only users with the same or higher security group can edit permissions. For example, a security group 5 user will not be able to edit security group 4 through 1 permissions. A user with a security group of 1 will be able to edit all permissions.

ADDING A CUSTOM GRAPHIC

You can change the graphic displayed in the upper-right corner of the various meter web pages. There are a few limitations:• The graphic must be in one of the following formats: JPEG, PNG, BMP, or GIF.



• The graphic size must be 143 pixels by 86 pixels. If it is larger than that, the meter will crop the graphic to that size (cropping occurs on the right and bottom).

• You must limit the color depth to 24 bit color or lower. The meter doesn’t support 32 bit color models.

To add a custom graphic:1. Right-click the graphic.2. Choose Select Custom Graphic...

3. In the Open dialog box, browse to the file on your local file system that you wish to upload.4. Select the file (its name should appear in the File Name field).5. Click the Select button.To revert to the default graphic:1. Right-click the graphic2. Choose Revert to PXM Photo (Default).

QUICK SETUP

The Quick Setup page provides quick access to the most common configuration settings. NOTE: Only users with Wiring and Meter configuration permissions will be able to edit the Quick Setup. The Quick Setup page provides access to:

• The Wiring Configuration selection• Enable/disable the Neutral Current (In), Ground Current (Ig), Calculated Neutral Current

(In) and Calculated Ground Current (Ig)• Phase Rotation and Frequency selections• Line-to-Line Voltage, the Potential Transformer (PT) Ratio, the Current Transformer (CT

Ratio), the Ground CT, and the Neutral CT selections • Energy units display format, such as meter ID

NOTE: If Neutral Current is selected, Calculated Neutral Current can NOT be selected and vice-versa. If Ground Current is selected, Calculated Ground Current can NOT be selected and vice-versa. Select one of the following wiring configurations based on the installation:

• Single phase 2 wire (1CT)• Single phase 3 wire (2CT)• 3 Phase, 3 wire (Delta 3 CT)• 3 Phase, 4 wire (Y 3CT)• 3 Phase, 3 wire (Delta 2CT)• 3 Phase, 4 wire (Y 3 CT, 2V) 2 1/2 Element• 3 Phase, 4 wire (center tapped Delta 3 CT)

Selecting Measure Ig allows you to view actual ground current. When Calculate Ig is selected, the meter estimates the ground current based on 3 phase and neutral current unbalance. Selecting Measure In allow you to view actual neutral current based on the 3 phase current unbalance. When Calculate In is selected, the meter estimates the neutral current.



NOTE: When both Measure In and Calculate In are selected, Measure In overrides the setting.Enter the nominal line to line voltage. The Nominal line to line voltage value is used as a reference for swells and sags monitoring.Select the Phase Rotation based on the Phase Rotation of the Input Voltages. Select the Nominal Frequency of the Input Voltages from the Frequency list.

Locating Quick Setup On The Web

1. From the Setup Main Page, select Quick Setup from the tree structure. The page will update to list all the current settings for Quick Setup. An Edit and an OK button will appear at the top of the page.

2. Click Edit to change any of the listed settings. 3. Click OK when new entries are completed.

CONFIGURATION FILES

Configuration files can be downloaded to your local file system and then uploaded from your local file system to a meter. This is a handy convenience feature, especially if you’re setting up multiple meters with either the same or similar settings. You can set up one meter, download the configura-tion file to your local computer, and then upload that same configuration file to other meters. If you want a hardcopy version of the meter settings, you can also create a formatted printout, Note: The configuration file is actually a ZIP file that contains multiple files, each with configuration

settings for a different aspect of the meter setup.To download the current configuration file:1. Click Save Config. File.2. Give the file a name (the dialog will fill in the .zip) extension.3. Click Save.To upload a configuration file to a meter:1. Click Load a Config. File.2. Select a .zip file.



3. Click OK.Note: If you aren’t logged in or you doesn’t have sufficient privileges, you’ll receive an authentica-

tion violation error message.To print the current configuration:1. Click Print all settings.2. Select a printer.To restore factory default settings:• Click Factory Reset.

VIEW & CREATE TRIGGERS SETUP

Event triggers can be automatic or manual. If you select manual triggering, the meter will use these programmed limits for event triggering. Each manual trigger input can be programmed to monitor performance, capture waveform, capture parameters, and/or send e-mail. When an event is triggered, the Reset Value will be used to check and clear the condition. Every event and its corresponding parameters, along with data and time of the occurrence, are logged and available for display or retrieval using a communication port. The Power Xpert Meter has seven kinds of triggers; Out of Limit, ITIC, Demand Overload, Subcycle Disturbance, Digital Input Status, Modbus Triggered, and Fast Transient. Input Status triggers are configured in the I/O section of the setup under Meter Setup & Commissioning. (See Internal I/O Input Setup). Modbus triggered events are not configurable, and as such are not shown here.

OUT OF LIMITS SETUP

The Out of Limits Triggers are divided into three categories; Meter, Power and Quality. Each have several options to choose from. Refer to Appendix C for a list of these options.

Locating Out of Limits Setup On The Web

1. On the Setup Main Page, select Triggers from the tree structure on the left side of the page. The tree structure will expand to list Out of Limits, Demand Overload, ITIC, Fast Transient and Subcycle Disturbance.

2. Click Out of Limits. The list will expand to include the main Out of Limits categories: Meter, Power, and Quality. Click a category to view or edit.

3. The list will expand again to include all of the options under the selected category. After a selec-tion is made, the page will update to list all the current settings for that trigger.



4. Edit and Delete buttons are provided beside each trigger for use in modifying existing triggers. 5. Use the Add New Trigger button at the top of the Out of Limits Trigger page to add an additional

trigger. 6. Click the Done button at the top of the Out of Limit Trigger Edit page when entries are com-

pleted.

DEMAND OVERLOAD SETUP

You can set Demand Overload for Real Power (forward, reverse, net, or sum), Apparent Power, Reactive Power (delivered, received, net or sum), and Current with a specific delay for each.

Locating Demand Overload Setup on the Web

On the Setup Main Page, select Triggers from the tree structure on the left side of the page. The tree structure will expand to list Out of Limits, Demand Overload, ITIC, Fast Transient, and Tran-sient. Click Demand Overload. The page will update to list all the current Demand Overload set-tings. Use the Edit button at the top of the page to edit settings. When selected, the page will update to display drop down boxes and text boxes for changing current settings. A Delete link is provided beside each item to remove an entry. A blank drop down box is also provided to add a new Demand Overload setting. When entries are completed, click the Done button located at the top of the page.



ITIC SETUP

ITIC Triggers are fixed triggers. Event triggers are dependent on levels of sag and swell conditions. You can select Capture Waveform, Capture Parameters, or choose to have an email sent when the event occurs.

Locating ITIC Setup On The Web

From the Setup Main Page, select Triggers from the tree structure on the left side of the page. The tree structure will expand to list Out of Limits, Demand Overload, ITIC, Fast Transient, and Tran-sient. Click ITIC. The structure will expand to list the main ITIC categories; Voltage Line - Line and Voltage Line - Neutral. Click the category to view or edit. The page will update to list all the current settings for the selected trigger. Use the Edit button at the bottom of the page to edit settings. When Edit is selected, the page will display check boxes for modifying current settings.



Click the Done button at the bottom of the page when entries are completed.

FAST TRANSIENT (AVAILABLE ON PXM8000 SERIES)

The Power Xpert Meter captures transients with optional hardware that samples 4 channels accord-ing to user settings. You can set the dv/dt Threshold and Absolute Threshold for Vag, Vbg, Vcg and Vng. You can also select the Sampling Speed as well as the kind of action that will occur when one of the thresholds has been reached [Capture Waveform, Capture Parameters, and/or Send E-mail]. The Absolute Threshold Voltage setting is intended to trigger on Voltage spikes that exceed the normal positive and negative peak values, which are typically 1.4 times the rms line-to-ground Volt-age. It is important to set this threshold safely above the expected peaks. The Setup page suggests a threshold that is 20% above the Nominal L-L Voltage (divided by the PT ratio). For example, a 120V/208V system has a 120V rms and 170V peak (line-to-ground), and so a 250V threshold is appropriate (i.e., 208 + 20%). The dv/dt Threshold setting is entered in dv while the dt is fixed at the hardware sampling rate. The Setup page suggests a conservative threshold to avoid false triggering. Specifically, the setup page suggests a threshold that is 50% above the Nominal L-L Voltage (divided by the PT ratio). A mod-erately aggressive lower threshold would be the 50% of the Nominal L-L Voltage (divided by the PT ratio). To calculate the volts per microsecond, multiply the threshold Volts by the sample time. For example, if the dv/dt Threshold is set a 10V and the speed selection is 6 Msps, the Volts per micro second would be 60 (i.e., 10V x 6 Msps = 60V/microsecond).

Locating Fast Transient Setup on the Web

From the Setup Main Page, select Triggers from the tree structure on the left side of the page. The tree structure will expand to list Out of Limits, Demand Overload, ITIC, Fast Transient, and Tran-sient. Click Fast Transient. The page will update to list all the current Fast Transient settings. Use the Edit button at the top of the page to edit settings. When Edit is selected, the page will display drop down boxes and check boxes for use in changing current settings. Click the Done button at the top of the page when entries are completed.



SUBCYCLE DISTURBANCE The Power Xpert Meter captures subcycle disturbances with its regular metering hardware, which samples at 30.72 ksps. You can set the dv/dt Threshold and Absolute Threshold for Van, Vbn, Vcn, Vab, Vbc, and Vca. In addition, you can select the kind of action that will occur when one of the thresholds has been reached; Capture Waveform, Capture Parameters and/or Send E-mail. The Absolute Threshold Voltage setting is intended to trigger on Voltage spikes that exceed the normal positive and negative peak values, which are typi-cally 1.4 times the rms line-to-ground Voltage. It is important to set this threshold safely above the ex-pected peaks. The Setup page suggests a threshold that is 20% above the Nominal L-L Voltage (divided by the PT ratio). For example, a 120V/208V system has a 120V rms and 170V peak (line-to-ground), and so a 250V threshold is appropriate (i.e. 208 + 20%). The dv/dt Threshold setting is entered in dv while the dt is fixed at the hardware sampling rate. The Setup page suggests an aggressive threshold. Specifically, the setup page suggests a threshold that is 5% of the Nominal L-L Voltage (divided by the PT ratio). To calculate the volts per microsecond, multiply the threshold Volts by 0.03072. For example, if the dv/dt Threshold is set at 20V, the Volts per micro second would be 0.744 (i.e. 20V x 0.0372 Msps = 0.744 V/ microsecond).A 30.72 ksps sampling rate and a pure 120V sine wave would result in a dv of 1.5V per sample at the zero crossing. A disturbed waveform would have a much higher dv/dt.Note: To notify Power Xpert software of subcycle disturbances, select the Send Web Services Notification box.



Locating Subcycle

Disturbance Setup on the Web

From the Setup Main Page select Triggers from the tree structure on the left side of the page. The tree structure will expand to list Out of Limits, Demand Overload, ITIC, Fast Transient and Subcycle Disturbance. Click Subcycle Disturbance. The page will update to list current settings. Use the Edit button at the bottom of the page to edit settings. When Edit is selected, the page will display drop down boxes and check boxes for use in changing current settings. Click the Done but-ton at the bottom of the page when entries are completed.

METER SETUP AND COMMISSIONING SETUP

The Meter Setup and Commissioning section of the Power Xpert Meter is broken into the following categories: Security, Compensation, Metering, I/O, Clock, Communication and System. These cat-egories contain setup information for Time of Use, PQ Index, Pulse Initiation, Hardware, Firmware, etc. Security was discussed earlier in this section. The remainder of the pages in this category will be discussed below.

COMPENSATION SETUP

The Compensation setup page allows you to compensate for errors within their PT and/or CT. The value entered is used by the meter to multiply with respective to voltage and current channels. The valid range is -10 to 10. A CT Compensation value with a negative sign could be used to reverse the sign of measured current. This allows you to correct the polarity if the CT wires are incorrectly



wired to the meter. For example, if a transformer had a 1% loss and the CT were wired backwards, the CT compensation would be -1.01.

Locating Wiring and Commissioning Setup on the Web

From the Setup Main Page, select Meter Setup & Commissioning from the tree structure on the left side of the page. The tree structure will expand to list Security, Compensation, Metering, I/O, Clock, Communications and System. Click Compensation. The page will update to list the current Com-pensation settings. Use the Edit button at the top of the page to edit settings. When Edit is selected, the page will display drop down boxes and check boxes for use in changing current settings. Click the OK button at the bottom of the page when entries are completed.

METERING SETUP

The Metering main category is divided into four subcategories, Demand, Time of Use (TOU), Load Profile and PQ Index. The following discusses each section and how to locate their respective information.

DEMAND SETUP

The Demand setup pages allow you to select either a Fixed Window or Sliding Window and the respective intervals in minutes. A fixed window setting allows you to select one interval period.



For example, if 15 minutes is selected, the demand calculation will be performed and the demand values will be updated every 15 minutes. With a sliding window setting, the Power Xpert Meter provides a rolling average; you select the interval period and the subinterval period. For example, if you select 15 minutes as the demand interval and 5 minutes as the subinterval, the demand will calculate every 5 minutes using the 3 subinterval values (15 = 5X3). The interval and subinterval value may be 1 to 60 minutes. If both values are the same, the demand interval is considered the fixed interval. A fixed interval period should be evenly divided by the subinterval value in case of a sliding interval.

Locating Demand Setup on the Web

From the Setup Main Page, Click Meter Setup & Commissioning from the tree structure on the left side of the page. The tree structure will expand to list Security, Compensation, Metering, I/O, Clock, Communications and System. Click Metering. The tree structure will expand to list Demand, TOU, Load Profile and PQ Index. Click Demand. The page will update to list all the current Demand set-tings. Use the Edit button in the top right corner of the page to edit Demand settings. When Edit is se-lected, the page will update to display radio buttons for use in modifying settings. When a selection is made, the appropriate interval periods can be entered. Click the OK button at the top of the page when entries are completed.



TIME OF USE (TOU) SETUP

Four rate periods are supported for Time Of Use (TOU); A, B, C, and D in addition to total rate (which is independent of time of use). At the start of a new demand interval, the Power Xpert Meter updates the TOU demand registers. If a scheduled rate change occurs, the demands are updated before the new rate is applied. The TOU schedule changes the rate and initiates a new demand window. The next demand window uses the new rate. The meter will support up to 64 rate schedules with day types of weekdays and weekend. Time of Use defines the Rate Schedule and the Calendar for the meter.

Rate Schedule Setup

The Power Xpert Meter has up to four user definable rate schedules. You can define the rate as a weekday or weekend and select the time the rate schedule is to begin. The rate schedule’s ending hour is defined by the beginning of another rate schedule. For example, Rate A is defined as a weekday beginning at 7:00 A.M. and ending at 4:59:59 P.M. when Rate B begins at 5:00 P.M.

Locating Rate Schedule Setup on the Web

From the Setup Main Page, select Meter Setup & Commissioning from the tree structure on the left side of the page. The tree structure will expand to list Security, Metering, I/O, Clock, Communica-tions, and System. Click Metering. The list will expand to list Demand, TOU, Load Profile and PQ Index. Click TOU. When the list expands again, click Rate Schedule. The page will update to list the current Rate Schedule settings. Use the Edit button at the top right corner of the page to edit any Rate Schedule listed or to add another setting. When the Edit button is clicked, the page will update to display Delete and Edit buttons beside each current schedule. Use these buttons to modify the corresponding rates. Click the Add Rate button to add another rate to the list. When Add Rate is selected, you will be prompted to select day, rate and time. When all settings are entered, click the Add button beside the newly entered line item.



CALENDAR SETUP

The TOU section provides the means to define the Calendar of Events. Dates can be selected for the meter to reset or send an e-mail. For example, you can add a date that specifies the meter to send an email every Friday or reset the demand on the 1st day or every month.

Locating the Calendar Setup on the Web

From the Setup Main Page, select Meter Setup & Commissioning from the tree structure on the left side of the page. The tree structure will expand to list Security, Compensation, Metering, I/O, Clock, communicatons and System. Click Metering. The list will expand to display Demand, TOU, Load Profile and PQ Index. Click TOU, then click Calendar. To enter a new calendar item, click Add Date. Drop down boxes will appear for use in selecting Day, Date, and Event. After making a selection, click the add button to add the item.To edit the existing calendar, click Edit and make changes to the selected item. Click OK when modifications are completed.



LOAD PROFILE SETUP

The Load Profile feature allows you to log and view interval values from Real Power (Forward, Reverse, Net and Sum), Apparent Power , Reactive Power, (Delivered, Received) Net and Sum, as well as Ampere. You can also set the log interval. The interval is 5 to 60 minutes. The Load Profile also provides a monthly profile, if enabled.

Locating Load Profile Setup on the Web

From the Setup Main Page, select Meter Setup & Commissioning from the tree structure on the left side of the page. The tree structure will expand to list Security, Compensation, Metering, I/O, Clock, Communications, and System. Click Metering. The tree structure will expand to list Demand, TOU, Load Profile and PQ Index. Select Load Profile. The page will update to display the current Load Profile Interval minutes and the monthly profile as enabled or disabled. Use the Edit button at the bottom of the page to modify the current interval and/or the monthly pro-file setting. When all settings are entered, click the OK button located at the top of the page.



PQ INDEX SETUP

The PQ Index page provides the means to rank the importance of the information captured on the power quality page. This is done by assigning a value from 0 to 50 for Swell, Sag, dv/dt, THD Voltage, THD Current, and Flicker. For example, if a user does not want the Power Quality page to recognize Flicker activity, the Flicker percent can be set to 0. Measurements of greater importance can be assigned higher values accordingly.

Locating PQ Index Setup on the Web

From the Setup Main Page, select Meter Setup & Commissioning from the tree structure on the left side of the page. The tree structure will expand to list Security, Compensation, Metering, I/O, Clock, Communications, and System. Click Metering. The tree structure will expand to list Demand, TOU, Load Profile, and PQ Index. Select PQ Index. The page will update to display the current PQ Index settings. Use the Edit button at the bottom of the page to modify the current value settings from 0 to 50. Click the OK button at the bottom of the page when entries are completed. The default is 10.0.



I/O SETUP

The I/O Setup section is divided into two categories; Pulse Initiation and Internal I/O.

PULSE INITIATION SETUP

The default mode for all outputs is Host Control. To select an output for Pulse Initiation, select this feature in the I/O Setup page, assigning a source and pulse constant . Pulse constants are handled differently for S1 and S2 verses R1, R2, and R3. S1 and S2 pulse constants are entered in second-ary rated Watt-Seconds per pulse (not including CT and PT ratios). R1, R2, and R3 pulse constants are entered in primary rated Watt-Hours per pulse. (CT and PT ratios are automatically factored.)The meter generates pulses through discrete or relay outputs based on the value of selected ac-cumulators. This is a fixed pulse and fixed width; 0 to 1000 kWh scaling factor. The meter can serve as a pulse initiator for all energies: real, reactive, or apparent. The Pulse Initiation Setup section allows you to select the Source and Pulse Constant for the two solid-state relay outputs (S1 and S2) and the three outputs (R1, R2, and R3). You can select Watt hours Forward or Reverse, VAR hours received or delivered, or VA hours and enter the Pulse Constant for each. For S1 and S2 (solid state outputs), the entered pulse constant is in Watt-second secondary. For example, if the CT Ratio is 5000:5, the PT Ratio is 120:120 and the pulse constant is set to 3600



Watt-Seconds, the primary rated pulse constant equals 1000 Watt-Hours per pulse. The S1 and S2 outputs pulse with a fixed width.R1, R2, and R3 are form C relays. In case the R1, R2, and R3 pulse constant value entered is Watt-Hour primary, the pulse output from these relays takes CT and PT ratios into account. R1, R2, and R3 relays change the state every time the energy value reaches the pulse constant value.

Locating Pulse Initiation Setup on the Web

From the Setup Main Page, select Meter Setup & Commissioning from the tree structure on the left side of the page. The tree structure will expand to list Security, Compensation, Metering, I/O, Clock, Communications, and System. Click I/O. The tree structure will expand to list Pulse Initiation, Internal I/O, and Remote I/O. Select Pulse Initiation. The page will update to display the current Pulse Initiation settings. Use the Edit button at the bottom of the page to modify current Pulse Initiation settings. Use the drop down boxes to select the source of each output and the text boxes beside the source to enter the pulse constant. Click the OK button at the bottom of the page when entries are com-pleted.



INTERNAL I/O SETUP

The Internal I/O Setup is divided into two subcategories, Inputs and Outputs. The setup page for each allows you to identify input or output and assign functionality to it.

INTERNAL I/O INPUT SETUP

The Internal I/O Input page lists each of the 8 digital inputs, their IDs, and function. The Function assigned to the digital input dictates what or how the digital input responds, as a Counter, calculat-ing summation log trends, giving Status via e-mail or capturing Waveforms, etc. Input 8 is fixed for real time pricing mode. Only one input can be selected for Demand Sync and DCF 77 Time Sync, and only input 8 can be configured for Real Time Pricing.

Locating Internal I/O Input Setup on the Web

From the Setup Main Page, select Meter Setup & Commissioning from the tree structure on the left side of the page. The tree structure will expand to list Security, Compensation, Metering, I/O, Clock, Communications, and System. Click I/O. The tree structure will expand to display Pulse Initiation, Internal I/O, and Remote I/O. Click Internal I/O. The structure will expand again. Click Inputs. The page will update to display the current digital input settings.



Use the Edit button at the bottom of the page to modify current settings. The page will display 8 digital inputs. Use the scroll bar on the right side of the page to view additional digital inputs. Use the ID text box to name the digital input if desired. Use the drop down box beside the ID to select the function (Counter, Status, Demand Sync, DCF 77, and Disable) of each digital input. Additional information may be required for some functions. For example, if Counter is selected, Pulse Weight, Pulse Multiplier, and Units must be entered. If Status is selected, the Delay time in seconds, the polarity of the input, and the triggering behavior must be set. In addition, the output settings, Log Event, Capture Waveform, and/or Send e-mail must be entered. Click the OK button at the bottom of the page when entry is complete.

INTERNAL I/O OUTPUT SETUP

The Output section of the Internal I/O contains three separate relay pages, R1, R2, and R3. Each of these pages list the relay’s ID, Mode, Trigger Type, Trigger, and Duration. You can associate each relay with up to 16 triggers. The Trigger Types are dictated by entries in previous setup pages. There are nine possible triggers types available to you; Out of Limits, ITIC Alarms, Subcycle Distur-bance, Fast Transient, Demand Overload, Input Status, Modbus Triggered, and End of Interval. If one of these setup pages is not completed or selected, the option will not be available in the drop down box for Trigger Type. If triggers are established for Out of Limits, Alarms and Demand Over-load, these options will be available in the Trigger Type drop down box. The Trigger drop down boxes provide options relative to the Trigger Type only. For example, if you select Out of Limits as the Trigger Type, the Trigger options will be restricted to the triggers set up in the Out of Limits setup page, such as: Phase AB Line - Line Voltage, System Real Power, etc. If the trigger is not setup in the previous page, it will not be available for selection in this page. One of the three modes; Latched, Timed, or Normal could be selected for a relay output.• In Latched mode, the relay is energized when a selected event occurs. The relay stays energized

until it is reset manually.• In Timed mode, the relay is energized for the duration specified when the event occurs.• In Normal mode, the relay is energized when the event occurs and de-energized when the event

is reset. Duration specifies the minimum time the relay will stay energized after recognizing the event.

Locating Internal I/O Output Setup on the Web

From the Setup Main Page, select Meter Setup & Commissioning from the tree structure on the left side of the page. The tree structure will expand to list Security, I/O, Clock, Communications, and System. Click I/O. The tree structure will expand to list Pulse Initiation, Internal I/O and Remote I/O. Click Internal I/O. The tree structure will expand to list Inputs and Outputs. Click Outputs. The tree structure will expand to list the three relays: RY1, RY2, and RY3. When a relay is selected, the page will update to display the current relay trigger settings. Use the Edit button at the bottom of the page to modify the current settings. All 16 triggers cannot be viewed at once. Use the scroll bar on the right side of the page to view additional settings that may not be displayed. Use the ID text box to name the relay output, if desired. Use the drop down box below the ID to select the Trigger Type and the Trigger from the options available. After these options are selected, choose the Mode from the drop down box and enter the duration. To add additional triggers for this relay, click the Add Trigger button at the top right of the page. Use the Delete button beside the Trigger to remove the Trigger Type from the relay. Click the Done button at the top of the page when entry is complete.



CLOCK SETUP

The Power Xpert Meter uses a real-time clock for time keeping. The meter can be configured to adjust for Daylight Savings Time (DST) based on the time zone selection and to synchronize time using NTP. By using NTP, time will be maintained by the real time clock, and the real time clock will be calibrated and time corrected using NTP. Note: The initial clock setting is in UTC/GMT (Greenwich Mean Time). The user-selected Time Zone only takes effect after clicking “OK”.The Clock setup allows you to set the time in hours and minutes, select a time sync option, and set the date for the meter. If NTP is selected for time synch, an IP address of the NTP server should be set. When selecting DCF-77 as the Time Sync Source, an Input channel must be selected under Meter Setup & Commissioning -> I/O. When selecting NTP (Network Time Protocol) as the Time Sync Source, at least one IP Address must be entered (as many as three NTP server IP addresses may be entered).Note: In order to retain the clock setting through a power cycle, the battery back up must be en-gaged. Set Switch D3 to the On position to engage the battery (See cover on power supply; Fig.2).

Locating the Clock Setup on the Web

From the Setup Main Page, select Meter Setup & Commissioning from the tree structure on the left side of the page. The tree structure will expand to list Security, Compensation, Metering, I/O, Clock, Communications and System. Select Clock. The page will update to display the current clock set-tings. To edit the settings, click the Edit button at the top of the page. Text boxes, radio buttons and drop down boxes will be displayed for this purpose. Click the OK button at the top of the page when modific ations are completed.



Use this page to enter the NTP server IP address for an Ethernet connection.



Select Input Setup to configure the appropriate inputs for a DCF-77 source. (See diagram in Ap-pendix G.)

COMMUNICATION SETUP

The Communication Setup section is divided into the following categories: COM1& 2, COM3, and Ethernet/LAN. COM 1 is provided as a standard feature with all Power Xpert Meters. The LAN/WAN COM 2 and COM 3 are included with the optional Communications Expansion card. The page for each of these categories displays the current settings and communications ports in use. The following sections discuss each category and their respective settings. NOTE: The CM Card RS 485 COM 1 is shipped from the factory as a slave port. Default jumper settings match this slave configuration. If the port configuration is changed to a master, refer to Appendix E for proper jumper placement instructions.

Locating Communication (COM 1, 2, 3, & Ethernet/LAN) Setup on the Web

From the Setup Main Page select Meter Setup & Commissioning from the tree structure. The tree structure will expand to list Security, Compensation, Metering, I/O, Clock, Communica-tions, and System. Click Communications. Then click the communication setup you wish to view or edit: COM1 & 2, COM 3, or Ethernet/LAN. The page will update to display the current settings for the selection.



NOTE: The CE Card RS485 COM 2 is shipped from the factory as a master port. Default jumper settings match this master configuration. If the port configuration is changed to a slave, refer to Appendix G for proper jumper placement instructions.

COM1 (CM3) & COM2 (CE3) SETUP

Use the COM1 & COM2 Setup page to: • Setup the Modbus RTU as a Master - Gateway, Slave - Gateway, Master - IO, or Modbus Slave.

For Slave, you can choose to communicate via Modbus ASCII or Modbus RTU. • Select a Modbus Slave addresses.• Select the Baud Rate, Stop Bits and Parity for the COM1 device on the CM3 port or the COM2

device on the CE3 port. NOTE: Only one of these ports can be configured as Master - Gateway.

SETUP

Click the Edit button at the top right of the page to modify current settings. Click the drop down list beside Modbus RTU to select if the device is a Master - Gateway, Slave - Gateway, Master - IO, or Modbus Slave. If Slave is selected, the slave address must be entered in the appropriate text box. Click the drop down box beside Baud Rate to select the appropriate rate; 9600, 19.2K, 38.4K, 57.6K, 115.2K. Click the drop down box beside Stop bits to select 1 or 2. Click the Parity drop down box to select None, Odd or Even. Note: If Slave - Gateway is selected, the meter will only respond to the slave address set via the hex switch on that port (Hex switch value + 15).



COM3 (CE4) SETUP

Use the COM3 Setup page to: • Setup the Modbus RTU as a Master - Gateway, Slave - Gateway, Master - IO, or Modbus Slave.

For Slave, you can choose to communicate via Modbus ASCII or Modbus RTU. • Select the Modbus Slave addresses.• Select the Baud Rate, Stop Bits and Parity for the COM3 device on the CE4 RS232 portThese options are the same as for COM1 and COM2 except that COM3 is an RS232 interface for one-on-one communication or multipoint through a modem. Note: To use COM3 (RS232) between a Power Xpert Meter Master Gateway and Slave-Gateway, use a null-modem cable that swaps RX with TX on the 9-pin D connector.

Locating COM3 Setup on the Web

From the Setup Main Page, select Meter Setup & Commissioning from the tree structure on the left side of the page. The tree structure will expand to list Security, Compensation, Metering, I/O, Clock, Communications and System. Click Communications. The tree structure will expand to list COM1 & COM2, COM and Ethernet/LAN setups. Click COM3 Setup. The page will update to display the current COM3 settings. Click the Edit button at the bottom of the page to modify the current settings. The page will update to display drop down boxes for use in editing each feature. Use Modbus RTU to select if the device is a Master - Gateway, Master I/O or a Slave. If Slave is selected, the slave address must be en-tered in the appropriate text box. Use the drop down box beside Baud Rate to select the appropriate rate; 9600, 19.2K, 38.4K, 57.6K, 115.2K. Use the drop down box beside Stop bits to select 1 or 2. Click the Parity drop down box to select None, Odd, or Even.



ETHERNET/LAN (CE1 & CE2) SETUP

The Ethernet/LAN Setup page allows you to select the kind of connection to be used (a fiber optic cable on the CE1 port or a 10/100 base T on the CE2 port), address information for the IP, the DNS Server and the Time Server (NTP), and to enable and configure the Modbus TCP.

Locating Ethernet/LAN Setup on the Web

From the Setup Main Page, select Meter Setup & Commissioning from the tree structure on the left side of the page. The tree structure will expand to list Security, Compensation, Metering, I/O, Clock, Communications, and System. Click Communications. The tree will expand to list COM1 & COM2 Setup, COM3 Setup and Ethernet/LAN. Click Ethernet/LAN Setup. The page will update to display the current settings of Ethernet/LAN. Click the Edit button at the bottom of the page to modify current Ethernet/LAN settings. Click the appropriate radio button to select the kind of port in use (10/100 base T or 100 base F). Enter the IP Address information or select Obtain Automatically. Enter the DNS Server Address or select Obtain Automatically. Lastly, enable Modbus TCP, if desired. Select Obtain Automatically if you have a DHCP server available. This allows the meter to obtain an IP address automatically. Enter an IP address if the NTP server of the NTP Time Sync option is selected in the Clock setup.Click the OK button at the top of the page to save your settings.



CONFIGURING MODBUS COMMUNICATIONS

When Modbus/TCP is enabled, it can be configured to accept connections from either all clients or trusted clients. You can set this by entering the IP address mask. The X.X.X.X setting ac-cepts all connections; however, you can also use the mask to accept connections from any client within a given subnet. For example, 192.168.X.X allows connections from any client in the subnet 192.168.0.0 to 192.168.254.254.You can also use the meter as a gateway to a Modbus subnet and the Ethernet/LAN Setup page provides settings for configuring the gateway. Either RS-485 serial port can be configured as the connection to the subnet; however, there are some tuning considerations, which are covered later, that may affect the choice of port. Either of the two RS-485 ports, or the RS-232 port, can be desig-nated Master-Gateway and Master-IO. These can be designated as such on the Com 1 & 2 Setup Edit page, and the Com 3 Setup page.

MODBUS TUNING

Modbus clients can respond differently to polling commands and may require additional time to respond. Also, the meter may need to attempt to poll a device multiple times as it may be in a state that does not allow it to immediately reply and therefore exceed the timeout value. You can use these settings to configure your the meter to accommodate the various requirements of the devices on the subnet. If there will be a high level of polling traffic, you should seriously consider having the Display Link on a separate RS485 port from the Modbus subnet. A high level of polling traffic can degrade



the performance of the Display Link. Modbus modes 3 and 4 allow you to automatically split the requests between the the two ports, depending on the slave device address. These are “load balancing” options as all Display Link address fall in the lower part of the range, and are therefore automatically routed to a particular RS485 port using these modes.

Modbus Timeouts

The following explains the Modbus timeout settings, and how to use them. These two settings com-bine to create a total timeout period (in ms) that equals the following formula:

Total Timeout = Subnet Timeout X (Subnet Retries value + 1)If a subnet device doesn’t respond within the Total Timeout, the meter responds with exception 11 (0xb) or “Gateway Target Device Failed to Respond.” Subnet Timeout This is the timeout value (or amount of time permitted for a subnet device to

respond to a command). The default value is 1000 ms. This can also be set via Modbus register 2005.

Subnet Retries The number of times the meter will retry a subnet command before issuing. The default value is 0 (or, “only try once”).

Modbus Subnet Gateway Configuration

The Subnet Mode field controls how the meter behaves as a Modbus subnet gateway. See page 6A-25 for instructions on configuring the RS485 ports (COM1, or if the Communications Adapter is installed, COM2.)0 Setting the Subnet Mode to zero disables the meter from functioning as a Subnet Gateway

Master. It will only respond to Modbus commands sent to its own slave address. The local ad-dress is the base address set by the hex switch.

1 This is the default setting for COM1 . Setting Subnet Mode to 1 enables the meter as a Modbus Subnet Gateway Master. This is the default setting for Com1The meter will route any commands to slave addresses (other than its own) to the RS485/RS-232 port set as a Master-Gateway. If no response is received from the slave device within the total timeout (specified above), the meter returns an exception 11 (0xB) “Gateway Target Device Failed to Respond.” If no RS-485 port is currently set as the Master-Gateway, the meter returns an exception 10 (0xA) “Gateway Path Unavailable.”

2 This is the default setting for Com2. Setting the mode to 2 also enables the meter as a Modbus Subnet Gateway Master. This is the default setting for Com2. The meter will route any commands to slave addresses (other than its own) to the RS485/RS232 port set as a Master-IO. If no response is received from the slave device within the total timeout (specified above), the meter returns an exception 11 (0xB) “Gateway Target Device Failed to Respond.” If no RS485/RS232 port is currently set as the Master-IO, the meter returns an exception 10 (0xA) “Gateway Path Unavailable.”

3 This is a load balancing option that requires that the optional Communications Expansion card has been installed. Unlike Subnet Gateway Master modes 1 and 2, the Gateway will route any commands to slave address (other than its own) to one of the RS485/RS232 ports, depending on the address. Slave addresses of 127 or below are routed to the RS485 port configured as a Master-IO while slave addresses of 128 or above are routed to the Master -Gateway.

As with the other Subnet Gateway Master Modes, if no response is received from the slave device within the total timeout (specified above), the meter returns an exception 11 (0xB) “Gateway Target Device Failed to Respond.” If no RS-485 or RS232 port is currently set as either the Master-Gateway or Master-IO, the meter returns an exception 10 (0xA) “Gateway Path Unavailable.”

4 This is another “load balancing” option that requires that the optional Communications Expan-sion card has been installed. The Gateway will route any commands to slave address (other than its own) to one of the RS485 or RS232 ports, depending on the address. Slave addresses



of 127 or below are routed to the RS485/RS232 port configured as a Master-Gateway while slave addresses of 128 or above are routed to the Master-IO.

If no response is received from the slave device within the total timeout (specified above), the meter returns an exception 11 (0xB) “Gateway Target Device Failed to Respond.” If no RS-485/RS232 port is currently set as either the Master-Gateway or Master-IO, the meter returns an exception 10 (0xA) “Gateway Path Unavailable.”

SNMP SETUP

The Power Xpert Meter supports Simple Network Management Protocol (SNMP) version 1, and provides information about the meter as per the following Management Information Bases (MIBs):

MIB Filename Description / UsageEaton Power Xpert Meter MIB EATON-PWR-MTR-MIB.txt Metered electrical system values.Eaton Alarms+Traps MIB EATON-PXG-MIB.txt Alarms and notifications (traps).Eaton Object Identifier (OID) assignments

EATON-OIDS.txt Base document for all OID as-signments for Eaton’s MIBs.

RFC 4133 Entity MIB ENTITY-MIB.txt Identification and description of each device

RFC 4268 Entity State MIB ENTITY-STATE-MIB.txt Five availability status meters for each device attached to the card

RFC 4268 Entity State MIB Part 2

ENTITY-STATE-TC-MIB.txt Possible state values for the Entity State MIB

Meter events (traps) are sent to designated SNMP manager devices. Traps may include such infor-mation as the ITIC event and time stamp as well as the event name and the meter name.When setting up the SNMP functionality, you can designate the following:SNMP Read Community String This is the meter password required to read information from

the meter. With this community string, the meter will respond to an SNMP GET REQUEST by sending the requested informa-tion via an SNMP GET RESPONSE.

By SNMP convention, this string defaults to public.SNMP Write Community String This is the meter password required to change meter settings.

With this community string, the meter will change the specified setting to the specified value when it receives an SNMP SET REQUEST.

SNMP Trap Community String This string identifies the meter to the SNMP manager receiving the trap.

SNMP Trap Agent This is the IP address of the SNMP manager that should re-ceive the traps. You can designate up to six IP addresses.



Locating SNMP Setup on the Web

From the Setup Main Page, select Meter Setup & Commissioning from the tree structure on the left side of the page. The tree structure will expand to list Security, Compensation, Metering, I/O, Clock, Communications and System. Click Communications. The tree will expand to list COM1 & COM2 Setup, COM3 Setup and Ethernet/LAN. Click Ethernet/LAN Setup. SNMP Setup will be displayed in the tree structure. Click SNMP Setup. Click the Edit button at the top of the page to modify current settings or to add additional e-mail ad-dresses. Click the OK button at the top of the page when entries are completed.

E-MAIL SETUP

The Power Xpert Meter can send email messages when an alarm is triggered or when a defined event has occurred. E-Mail client could be setup to send periodic emails or alarm emails. The option to send an email is available on other pages, such as Time of Use and Alarms. The E-Mail Setup page contains information about where to send an email notification and what to include in each e-mail. Use the TOU (Time of Use) calendar setup to configure perioidic emails Use the trig-ger set up page to configure alarm emails. Use the E-Mail Setup page to configure the email client. Enter the Email account and password. Enter the email address recipients. Up to 5 email address can be entered. Select when to send an email by selecting Periodic or Alarm. Select the content of the email. Emails may be sent to up to five separate email addresses. The Email page contains the meter’s account name. This is the name entered into the server or the server account name, the SMTP Server, and the email addresses.A periodic email will be sent if email was selected for any dates on the Calendar setup page. Refer to the Calendar Setup for additional information. An email will be sent if the email option was se-lected on any of the Trigger setup page.

Locating Email Setup on the Web

From the Setup Main Page, select Meter Setup & Commissioning from the tree structure on the left side of the page. The tree structure will expand to list Security, Compensation, Metering, I/O, Clock, Communications and System. Click Communications. The tree will expand to list COM1 & COM2



Setup, COM3 Setup and Ether-net/LAN. Click Ethernet/LAN Setup. E-Mail Setup will be displayed in the tree structure. Click E-Mail Setup. Click the Edit button at the bottom of the page to modify current settings or to add additional e-mail addresses. Click the OK button at the bottom of the page when entries are completed.

SETTING UP EMAIL

On the E-mail Setup page, you must fill in four pieces of information to connect to an SMTP server:• Account: This is the email account used to log into the mail server.

You (or your IT group) must create an email account on your mail server for use by the meter.

• Password: This is the password for the email account used by the meter. Presently, this field has no function as the meter firmware does not yet support a connection to the mail server using TLS or SSL.



• SMTP Server: This is the name or IP address of your SMTP mail server. If you don’t know the name of your server, contact your IT group.

• SMTP Port: This is the port number assigned for SMTP [default is 25]. Port numbers allow mul-tiple applications to share the Ethernet hardware without interfering with each other.

On the Ethernet/LAN Setup page, you must also set:• At least one DNS Server.• The fully qualified domain name. This is concatenated from the Host Name on the E-mail

Setup page and the Domain Name on the Ethernet Setup page. For example, for a Host Name of meter1 and a Domain Name of mydomain.com, the resultant fully qualified domain name is meter1.mydomain.com.

Your IT group should ensure that the Hostname is set as the reverse lookup name for the meter in DNS. If the meter has been assigned a static IP address, you can normally check if the Hostname has been properly configured in DNS by running the following from a Windows command prompt:> nslookup meter_ip_address

where meter_ip_address is the IP address assigned to the meter, terminated with a dot [‘.’]. If the meter’s Hostname has been properly configured in DNS, you should see the Hostname returned by the command.

WEB SERVICES SETUP

The Web Services setup page was designed to provide controls for communications with Power Xpert Software. For optimum Power Xpert Software communications, the trending data updates are set at 15 minute intervals, which is a strongly recommended and required setting for larger net-works, especially those with multiple meters. Shorter intervals may severely degrade performance. You should also leave alarm notification active.The Web Services setup page also has an Install SSL Certificate button. This is a link which will open the Root Installation CA page for the meter. From this page, you can install an SSL certificate which will allow https communication between your web browser and the meter. For more informa-tion about installing a security certificate, see page 279.



SYSTEM SETUP

The System Setup page is divided into two sections: Hardware and Firmware. These pages have no user changeable fields. They display pertinent hardware and firmware information.

HARDWARE SETUP

The System Hardware page lists the models/versions and manufacturing information of the:• Core Board• Power Supply• Communication Main Board (including MAC address)• Communication Expansion Board• I/O Board

This page also lists the Compact Flash and System Flash Total Memory and Available Memory and availability of FPGA for Fast Transient Capture.The MAC address is also found on this screen, as part of the Communication Main Board.

Locating Hardware Setup on the Web

From the Setup Main Page, click Meter Setup & Commissioning from the tree structure on the left side of the page. The tree structure will expand to list Security, Metering, I/O, Clock, Communica-tions, and System. Click System. The tree structure will expand to list Hardware and Firmware. Click Hardware. The page will update to display Hardware information.



FIRMWARE SETUP

The System Firmware page displays the Power Xpert Meter Firmware Version and the date of release with buttons to upgrade firmware update and reboot the meter.

Locating Firmware Setup on the Web

From the Setup Main Page, select Meter Setup & Commissioning from the tree structure on the left side of the page. The tree structure will expand to list Security, Compensation, Metering, I/O, Clock, Communications and System. Click System. The tree structure will expand to list Hardware and Firmware. Click Firmware. The page will update to display the Firmware version. Refer to Firmware Upgrade, for the upgrade procedure.


9 Setup on the Graphical Display

9 SETUP ON THE GRAPHICAL DISPLAY

When the Setup screen is selected on the local graphical display, the screen below will be dis-played. The user can view information or edit information. All configuration (edit) abilities require a password to complete. Click on one of the selections to view and/or edit the detailed information about that selection. NOTE: A pop up box will display an error message if an invalid entry is attempted.

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View Setup

Edit Setup

Login Logout

The Setup main screen



9.1. Log In

Text can be entered in upper case and lower case. Grammatical marks are available as well as delete (Del) and enter (Ent ↵). The Power Xpert is programmed from the factory with a user/password combination of upper case X for both the user and the password. To log in:1. Press the navigation dial to select the upper field and rotate the navigation dial counter-clock wise until the upper case X is displayed. 2. Press the dial to select this character. Rotate the dial clock wise until the Enter symbol (Ent ↵) is highlighted. 3. Press the dial to enter the upper case X for the user name. 4. Rotate the dial to select the password field. 5. Repeat the process to select the upper case X for the password. This will complete the login procedure.

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OK Cancel

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View Setup

Edit Setup

Login Logout

X



9.2. Quick Setup

Turn the navigation dial to select/highlight a topic. Press the dial to access information about that topic. If you must be logged in to edit the set up selections. The Quick Setup includes the basic metering configuration options required for metering and for

default power quality features, such as ITIC, to function properly.

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View Setup

Edit Setup

Login Logout

Quick Setup...

View & CreateTriggers...

Meter Setup and Commissioning...


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208 V Next

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Wiring Configuration:

Phase Rotation:

3 Phase 4 Wire (V 3 CT)

Frequency: 60 Hz

Line to Line Voltage:

ABC

Quick Setup Screen 1

Singe Phase 2 Wire (1CT)Single Phase 3 Wire (2CT)3 Phase 3 Wire (Delta 3CT)3 Phase 4 Wire (V 3CT)3 Phase 3 Wire (Delta 2CT)3 Phase 4 Wire (V 3CT)3 Phase 4 Wire (V 3CT 2V) 2 1/2 Element3 Phase 4 Wire (CTRTAP Delta 3CT)



To edit numeric values, select/highlight the entire number string to be modified. Press the naviga-tion dial. Only the first digit in the number string will be highlighted after the dial is pressed. Turn the dial to increment or decrement (0-9) the highlighted number. When the desired number value is displayed, press the dial to lock in the selection. The next digit to the right will automatically become highlighted. This process allows the user to modify each number individually.As the dial is turned, delete (Del) and enter (Ent) commands are displayed between 0 and upper case Z. Use the delete command to remove a number. For example, if delete is selected for the first digit in the number, 7220, the 7 will be removed and the new number will be 220. Use the enter command to lock in a selected digit. Continue until all modifications in the selected number string are completed. Click on Submit to complete/exit the setup.

120 : 120

Submit

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PT:

CT:

Ground CT:

Neurtral CT:

5000 : 5

5000 : 5

5000 : 5

Quick Setup Screen 2



9.3. Meter Setup and Commissioning

Any user can view the setup, but to make changes you must login with a valid username and pass-word. The factory default username and passward are both an upper case X.Using the naviagation dial, select the desired setup option from the list onthe Meter Setup and Commissioning screen and enter the appropriate value.

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View Setup

Edit Setup

Login Logout

Quick Setup...


Meter Setup and Commissioning...


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Select Setup Option:

ExitWiring & ConfigurationFrequencyIncoming L-L voltagePT PrimaryCT PrimaryGround CTNeutral CTDemand Interval PowerTime Set/Date Set

Com 1Com2EthernetNamePQ Index ConfigurationDemand OverloadPulse InitiatorSystem HWSystem FWDiagnosticsSecurity

Metering and Commissioning Screen



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View Setup

Edit Setup

Login Logout

9.4. “Setup” This Display (Screen contrast, etc.)

To make changes, you must be logged in. From the list of options, select “Setup This Display.” The Setup Display screen will appear. Select the option you wish to adjust and press the navigation

dial. This screen also enables the user to enable or dis-able the alarm buzzer.

Setup This Display Screen

Contrast

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Off

Back Light

Buzzer

Disable

Quick Setup...


Meter Setup and Commissioning





9.5. Network, Firmware & Product Information

To view information about the device, turn the navigation dial until Select a Device is highlighted in the upper right corner of the screen. Press the navigation dial. The next screen will display the op-tion to select the Display Unit or to go to the main meter screen. Select the Display Unit option and press the navigation dial. Network, Firmware and Product information options will appear at the

bottom of the screen. Select the information you wish to view. The screens that support this informa-tion are displayed on the bottom of the page.

Display Network Settings:

Front Panel IP Address : 192.168.1.1

Front Net Mask : 255.255.255.0

Front MAC Address : 00.d0.

Back

Display Product Information:Control Number : xxxxxxStyle Number : xxxxxxRevision Level : xxxxxxSerial Number : xxxxxxDate Code : xxxxxx

Back

Display Firmware Information:

Firmware Version : 1.0.1

Firmware Date : 2006/02/10

Back

Contrast

Display Unit

Off

Back Light

Buzzer

Disable

Select a Device

Network Settings

Production Information

Firmware Information

Select a Device:

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Contrast

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Off

Back Light

Buzzer

Disable

Select a Device



9.6. Password Setup

You must be logged in to change passwords. Any user can change their own password; however, you must be logged in as a user with sufficient permissions to change other users’ passwords.To set a password for a user:1. Highlight Setup and push the dial.2. Highlight Edit Setup and push the dial.3. Highlight Meter Setup and Commissioning and push the dial.4. Push the dial to enter the list.5. Turn clockwise until Security is highlighted and push the dial.6. With User highlighted, push the dial.7. With the top field highlighted, push the dial.8. Enter user name and then select Enter (Ent).9. Highlight the lower field.10. Push the dial.11. Enter the new password and then select Enter (Ent).12. Highlight OK and then press the dial.

OK

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Set Password For User:

New Password

Password Setup Screen


10 Firmware Upgrade

10 FIRMWARE UPGRADE

The Power Xpert Meter and display firmware is field upgradeable. Firmware can be remotely upgraded using a web interface by connecting through any Ethernet port pro-vided on the display or the meter. Mulitple meters in the RS485 sub-network also can be upgraded when connected through the meter configured as a gateway.Important! Make certain that you download the correct firmware for the PXM4000/PXM6000/PXM8000 meters. Firmware for previous versions of the Power Xpert Meter, with model numbers of PX4xxx, PX6xxx, or PX8xxx is not compatible with the PXM4000/PXM6000/PXM8000 meters.

10.1. Locating & Upgrading System Firmware on the Web

Locate and download the firmware on the www.eaton.com/pxm web site. Save the firmware upgrade zip file in the PC. Click on the Upgrade button on the System Firmware screen. Options for the upgrade will be displayed.

Select the device you wish to upgrade from the left side of the screen. When a PC is con-nected to the meter, a display unit is listed as the Master Device. If a PC is connected to the Display Ethernet port, the display is listed as the Display. Always upgrade the display unit before upgrading the meter. Locate and select the Firmware upgrade by clicking on the Choose Upgrade File button and then browsing the directory with the pop up file browser. Enter the user name and password. The user must have permission to upgrade the firmware. The administrative password will work.

www.eaton.com/pxm


10 Firmware Upgrade

Clicking the “Licenses” button displays the open source software licenses.

Click on the Start Upgrade button to start the firmware upgrade on the selected device. When the upgrade begins, a pop-up progress window will be displayed.When the upgrade is completed, the user will be prompted to reboot the unit. Connection to the device will be lost at this point. Close the browser and reconnect after the reboot. Check the firmware version by navigat-ing to the System Firmware screen.


10 Firmware Upgrade

NOTE: Changes to the user interface code in the new firmware will not appear if the cache is enabled in the Java Control panel. It is important to disable the cache and disable any proxy settings for local connections so that the PowerXpert can run the web interface properly. This process is explained in the following section.

DISABLING THE CACHE AND PROXIES

To change the Java Settings: 1. Launch the Windows Control Panel. 2. Click the Java icon/entry. 3. On the General tab, click the Network Settings... button. 4. Choose the User proxy server option, but leave the proxy server blank.


10 Firmware Upgrade

5. Select the Bypass proxy server for local addresses checkbox.6. Click OK.7. On the General Tab, click the Settings button in the Temporary Internet Files

area.8. Click the Delete Files... button.

9. Select Applications and Applets in the Delete Temporary Files dialog box.10. Click OK.11. Click OK In the Temporary Files Settings dialog box.12. Click OK in the Java Control Panel.


10 Firmware Upgrade

10.13. Upgrading From a PXM4000 to a PXM6000

You can upgrade a PXM4000 meter to a PXM6000 meter via a firmware upgrade. The Web interface to the PXM4000/PXM4200 meter has a link on the Main Screen (over the non-functional Power Quality Index), the ITIC Curve, and the Calendar/Timeline Event views that lead to a web page from which you can purchase the upgrade to the meter. Simply click the Click here to upgrade button on any of these pages.

Clicking the link will launch a browser window and open the PXM4000 to PXM6000 up-grade page on the Eaton web site. Follow these general steps to purchase a license file.1. Create a user account (if you don’t already have one). You can click the New User

Registration link and fill out the form to create your account.2. Select the number of upgrade licenses you wish to purchase. This is a typical web

store process, with a shopping cart and a checkout procedure. You’ll need a credit card to purchase license key files this way.

3. After you purchase upgrade license(s), you’ll be emailed license file(s) which you can use to upgrade the meter(s). You will need a separate license file for each meter that you wish to upgrade.

To upgrade the meter: Upon clicking the Click here to upgrade button, the meter switches to the upgrade window. If you wish to upgrade the meter at a later time, you can return to the hardware page via Meter Setup and Commissioning > System > System Hardware on the Setup tree.


10 Firmware Upgrade

1. Click the PXM 6000 Upgrade button on the System Hardware page.If you aren’t logged in, the login page appears. Enter the administrative user name and password (the default is user = admin, password = admin). Navigate back to the Meter Setup and Commissioning > System > System Hardware page. Click the PXM 6000 Upgrade button again.

2. In the file browser dialog box, browse to the license file (it has a .LICENSEKEY exten-sion).

3. Click Open.After a successful upgrade, the meter part number (displayed on the hardware information page) will have a “u” appended to it.


11 Troubleshooting & Maintenance

11 TROUBLESHOOTING & MAINTENANCE

11.1. Level of Repair

This manual supports unit-level troubleshooting only. If the cause of a malfunction is traced to the Power Xpert Meter Module, replace the unit. Return the faulty unit to Eaton for factory repairs.

11.2. Warnings!

SHOCK HAZARDS:ALL MAINTENANCE PROCEDURES MUST BE PERFORMED ONLY BY QUALIFIED PERSONNEL. Failure to observe this warning could result in serious injury, death and/or equip-ment damage.TROUBLESHOOTING PROCEDURES MAY INVOLVE WORKING IN EQUIPMENT AREAS WITH EXPOSED LIVE PARTS WHERE THE HAZARD OF A FATAL ELECTRIC SHOCK IS PRESENT. Personnel must exercise extreme caution to avoid injury or death.

ALWAYS DISCONNECT AND LOCK OUT THE CURRENT SOURCE AND CONTROL POWER SUPPLY BEFORE TOUCHING THE COMPONENTS ON THE REAR OF THE METER.

CLEANING: REMOVE THE POWERXPERT FROMLINE POWER WHEN CLEANING. Do not use water or any liquid cleaning product. Clean the unit with a clean dry cloth only.

11.3. Maintenance and Care

The Power Xpert Meter is designed to be a self contained and maintenance free unit. The printed circuit boards are calibrated at the factory. They are intended for service by factory trained person-nel only.The Power Xpert Meter should be stored in an environment that does not exceed the storage tem-perature range of -40O to 85O C. The environment should also be free of excess humidity. If possible, the device should be stored in its original packing material and container.

11.4. Calibration

The Power Xpert Meter is permanently calibrated at the factory. Further calibration in the field is not necessary. Calibration can be verified via the pulse initiator relays that are available on the optional I/O card.

11.5. Technical Assistance

The Troubleshooting Matrix that follows is provided to aid service personnel in identifying the origin of a malfunction. For additional information, technical assistance or referral to a local authorized distributor, contact Power Quality Technical Support at 1-800-809-2772 option 4. You can also e-mail the team at [email protected] or visit us on the Web at www.Eaton.com. Select the Products tab and follow the Power Management product link.



11.6. Return Procedure

If an internal malfunction is identified, the unit should be returned to the factory for repair or replace-ment. To have a unit returned, contact your Eaton authorized distributor with your system hardware and system firmware identification information. This information can be found in the Setup System area of your Meter. See the Setup chapter for additional information.

11.7. Resetting the Meter to Factory Defaults (Web Browser)

A factory reset may take up to five minutes to complete. Once you’ve confirmed the reset from the web interface, please close your browser window and the wait five minutes before reconnecting to the unit.

To reset the meter to factory defaults with a known username and password:1. Open a web browser and navigate to the meter by typing its IP address into the web browser’s

address field.2. Once the web interface has loaded, click on the Setup button.3. On the setup screen, click the Login / Change Users button to log in.4. Log in as an administrator level user. If you do not know your admin username and password,

please contact Eaton Support for instructions on how to recover a lost username and password.5. Once you are logged in, click on the Quick Setup link in the left-hand pane.6. Click the Factory Reset button.7. A confirmation dialog box will appear. Click Yes to confirm the factory reset. Doing so will erase

all data on the unit, and clear all of its settings.8. Make note of the time, it will take approximately five minutes for the meter to complete its fac-

tory reset. 9. Once the green LED on the left side of the meter module has returned to a slow blink pattern

(one second on, one second off) the meter is ready to be configured.NOTE: the CE Card Ethernet settings will have been lost during factory reset, please log into the meter using the local configuration port to configure the meter.

11.8. Com Reset Switch

Located above the rotary switch, the Com Reset switch can be used in conjunction with the DIP switches on the power supply front panel to reset the meter’s communications ports. The reset switch has the following functions, depending on the DIP switch settings.

DS -1 DS-2 DS-3OFF OFF ON Initialize all communicadtions ports to their

factory default settings.

OFF ON ON Initialize the LAN/WAN and Local Config communications ports and assign the fol-lowing IP addresses: LAN/WAN: 10.1.1.1 Local Config: 192.168.1.1



DS -1 DS-2 DS-3ON OFF ON Attempt to recover communications via

the LAN/WAN port by disabling then re-enabling the communicadtions port.

ON ON ON or OFF

Factory Test Mode - The meter should never be operated in this mode. The meter will indicate that it’s in factory test mode through a repeating series of three flashes on the red Status LED.

11.9. Operating in Safe Mode

For normal operation the default position of DS-3 is ON. With DS-3 OFF the meter operates in Safe Mode. While in this mode, the meter runs Linux and telnet for troubleshooting but does not run the metering application. Diagnosis and repair can be performed over the Local Configuration port. The meter responds to ping and provides a telnet server, but webpage, web-service, and Modbus are disabled.

11.10. Troubleshooting Matrix

Symptom Probable Cause Possible SolutionMeter Status LED repeats 3 red blinks

If the Status LED repeats a red 3-blink pattern, the meter is in self-test mode.

1. Remove power from the meter.

2. Locate the DIP switch ar-ray on the lower right side of the meter face.

3. If switches 1 & 2 are in the ON position (to the left) the meter is in factory test mode. Select one of the following switch configura-tions instead:

4. 1 (OFF) 2 (OFF) - no security, ID and password required.

5. 1 (OFF) 2 (ON) - medium security, energy & de-mand resets prohibited.

6. 1 (ON) 2 (OFF) - high security - configura-tion changes, energy & demand resets prohibited, ADMIN/ADMIN accepted 15 minutes after boot-up.

7. Re-apply power to the meter.



Symptom Probable Cause Possible SolutionHealth LED is blinking green quickly (faster than once per second).

Setup file is missing following a firmware upgrade.

Review & enter Quick Setup, Triggers, Communication, Clock Settings & reboot the meter. Several reboots may be required.

All operator panel indicator LEDs are off.

Line voltage level is deficient.Separate source control power is deficient.

Locate cause of deficiency in AC line monitored.Locate cause of deficiency in the AC control power line.

AC line connections or op-tional external voltage trans-formers are not properly wired or installed.

Verify the the AC line and/or potential transformers are wired as shown on the appro-priate wiring drawing.Verify line voltage.

Blown or loose fuses. Check fuses(s) on effected phase(s). Reset fuse(s) and replace if necessary. If the problem persists, replace the unit.

Meter set for Factory Test Mode.

Depending on the firmware version, the meter may be set for factory test mode. Refer to the “Meter Red Status LED repeats 3 blinks” section at the the beginning of this matrix.

Power Xpert Meter has mal-functioned.

Replace the unit

Meter is not in list of de-vices.

Display Unit just powered-up. On display unit power-up, it can take up to two (2) minutes for the display to recognize all meters on the network.

Duplicate Base Address Make sure that the meter in question has a unique base address. The base address is set on the rotary switch on the lower-left of the housing.

Voltage and current readings are incorrect and unstable.

The case is not grounded. Attach ground wire to meter Earth Ground terminal.

VR unreferenced. Attach to metering ground or case ground.

Min/Max/Average Trend data does not appear on the Trend and Min/Max charts.

Timestamped data is inconsis-tent with the real-time clock.

Verify that the battery switch is ON (SW3 on the PXPS-1/PXPS). Enter the correct time and Reset the Trend data (right click menu). Reboot the meter.



Symptom Probable Cause Possible SolutionOne or more voltage phase(s) read incorrectly.

Blown or loose fuses. Verify line voltage.

Incorrect voltage setting. Check fuses(s) on effected phase(s).

One or more currents read incorrectly.

Incorrect current transformer ratio setting.

Verify incoming current to the meter with separate ammeter.Verify correct settings pro-grammed in ther meter for system type, L-L voltage and PT rating.

CT Shorting Screws Power values are low when CT shorting screws are in place. Typically, the imped-ance of shorting screws is not much less than that of PXM’s current inputs.

Power parameters (Watt, Var, VA, Power Factor) read incorrectly.

Phasing for voltage and cur-rent is mismatched.

Examine the phasor diagram as seen on the Meter web page and compare phase angles of Va, Vb, Vc, Ia, Ib, Ic, to detect possible mis-wiring. The phasor diagram is also available on the Local Display by using the following path: Meter > VagL-L Voltage > Vavg > Phasor.

Current transformers polarity is reversed.

Verify connections per wiring diagrams.Reverse current trans former leads. Verify ground wiring per drawings.Reverse current polarity via settings. Enter password and change CT compensation in Setup mode. A CT compen-sation value of - 1.0 has the effect of reversing polarity.

CT Shorting Screws Power values are low when CT shorting screws are in place. Typically, the imped-ance of shorting screws is not much less than that of PXM’s current inputs.

Unit fails to detect contact closure on Discrete Contact Inputs.

Discrete Inputs not properly configured.

Check meter setpoints.

Excessive ext contact resis-tance.

Contact must be compatible with 24Vdc, 10 mA.

Improper wiring or faulty ex-ternal device providing contact closure.Contact welded.

Verify that external contact actually closes and that imped-ance is essentially zero when contact is closed. Also, verify wiring to Discrete Contact inputs per drawings.



Symptom Probable Cause Possible SolutionSlave devices on the master side of the open circuit con-tinue to communicate; how-ever, the slaves on the far side do not communicate.

One or both conductors in the RS-485 bus are broken.

Open Circuit, check RS-485 connection.

TXD LED does not flash Incorrect hardware configura-tion.Hardware failure.

Reconfigure hardware.Repair or replace hardware.

TXD LED flashes, RXD LED doesn’t.

There’s a problem in the com-munications channel connect-ing the PC to the LED.

Trace the signal from the com-munications channel to the meter. Determine where the signal is being interrupted and correct the problem. Data rate or frame mismatch.

Frequency variation is higher than expected.

VR terminal is floating. Wire VR terminal to earth/ground reference.

Default “admin” and “X”UserID/Password sets do not work.

UserID/Password forgotten. Remove the tamper seal-able security cover from the PXPS-1 or PXPS-4 card. Move the Mode 1 and Mode 2 switches to the OFF posi-tion. Cycle power to the meter. Login as “ADMIN” with the “ADMIN” password within 15 minutes. Setup new adminis-trator-level UserID/Password. Return to secure mode with the Mode 1 or Mode 2 switch in the ON position. Reinstall the tamper sealable security cover. Reboot the meter.

Cannot connect over the LAN/WAN Ethernet.

Duplicate IP Address. Network requires a Domain namePC arp table contains an old MAC Address for the given IP Use DHCP to automatically assign a unique IP address. Once a Domain name is ac-quired, turn off the automatic setting and enter the Domain Name setting.Clear the PC’s arp table (e.g., arp-d on the Windows com-mand prompt).



Symptom Probable Cause Possible SolutionWeb interface through LAN/WAN CE2 port not working

Network or hardware problem. Try the following to isolate the cause:

Unplug CAT5 connector from Display Unit Ethernet port and then reconnect with firm push.Verify IP address using either Local Configuration Port or through the Local Display. The IP address can either be static or dynamic. Verify that IP and DNS are both set to either fixed or DHCP. Verify that FIBER is disabled.If link light is not lit, a cross-over cable may be required.Ping IP address, verify Link light is lit and Tx/Rx activates (from Windows command prompt, type: ping ip_ad-dress).Verify the laptop IP address is compatible with LAN/WAN (from the Windows command prompt, type: ipconfig)

Check for duplicate devices with duplicate IP address on the LAN/WAN. Unplug the meter from the LAN/WAN and ping for its IP address.Clear Internet Explorer’s proxy server configuration. Access this through the Connections tab on Tools > Internet Op-tions. Click the LAN Settings button and deselect Proxy server.Clear the ARP cache (from the Windows command prompt, type: arp -d)Turn off auto-negotiate 10/100 for your NIC or Ethernet hub.At the meter, remove power and then remove the compact flash (CF) card. Re-insert the CF card and reapply power. If web interface now works, replace the CF card.



Symptom Probable Cause Possible SolutionWeb interface through LAN/WAN CE1 port (fiber, 100FX) not working


Verify IP address using either Local Configuration Port or through the Local Display. The IP address can either be static or dynamic. Verify that IP and DNS are both set to either fixed or DHCP. Verify that FIBER is disabled.Ping IP address, verify Link light is lit and Tx/Tx activates (from Windows command prompt, type: ping ip_ad-dress).Verify the laptop IP address is compatible with LAN/WAN (from the Windows command prompt, type: ipconfig).Check for duplicate devices with duplicate IP address on the LAN/WAN. Unplug the meter from the LAN/WAN and ping for its IP address.Clear Internet Explorer’s proxy server configuration. Access this through the Connections tab on Tools > Internet Op-tions. Click the LAN Settings button and deselect Proxy server.Clear the ARP cache (from the Windows command prompt, type: arp -d)At the meter, remove power and then remove the compact flash (CF) card. Re-insert the CF card and reapply power. If web interface now works, replace the CF card.Remove power from meter and reseat communications card. Apply power.



Symptom Probable Cause Possible SolutionWeb interface through Display Unit 10/100 or local configuration ethernet port not working


Make sure laptop is either connected to Display Unit via a cross-over cable or through an Ethernet hub. Note: if either the display or laptop is equipped with automatic MDI/MDI-X config feature, a standard CAT 5 patch cable will workPing 192.168.1.1, verify Link light is lit and Rx/Tx activates (from Windows command prompt, type: ping 192.168.1.1).Unplug CAT5 connector from Display Unit Ethernet port and then reconnect with firm push.While Display Unit port IP ad-dress is fixed at 192.168.1.1, it falls back to 10.1.1.1 if the LAN/WAN CE2 is set to an IP address of 192.168.1.x. Try 10.1.1.1.Verify the laptop IP address is set to 198.168.1.x (from the Windows command prompt, type: ipconfig).Clear Internet Explorer’s proxy server configuration. Access this through the Connections tab on Tools > Internet Op-tions. Click the LAN Settings button and deselect Proxy server.Clear the ARP cache (from the Windows command prompt, type: arp -d)Turn off auto-negotiate 10/100 for your NIC or Ethernet hubAt the meter, remove power and then remove the compact flash (CF) card. Re-insert the CF card and reapply power. If web interface now works, replace the CF card.



Symptom Probable Cause Possible SolutionModbus LAN/WAN CE2 port not working

Try the following: Modbus TCP/IP address = xxx.xx.xxx.xxx. The Meter ID is determined from the Base Address setting on rotary switch (lower left of meter housing).Unplug CAT5 connector from Display Unit Ethernet port and then reconnect with firm push.Verify IP address using either Local Configuration Port or through the Local Display. The IP address can either be static or dynamic. Verify that IP and DNS are both set to either fixed or DHCP. Verify that FIBER is disabled.If link light is not lit, a cross over cable may be required.Ping IP address, verify Link light is lit and Tx/Rx activates (from Windows command prompt, type: ping ip_ad-dress).From the Windows command prompt, type: ipconfig.Unplug the meter from the LAN/WAN and ping for its IP address.Access this through the Con-nections tab on Tools > Inter-net Options. Click the LAN Settings button and deselect Proxy server.From the Windows command prompt, type: arp -dTurn off auto-negotiate 10/100 for your NIC or Ethernet hub.At the meter, remove power and then remove the compact flash (CF) card. Re-insert the CF card and reapply power. If web interface now works, replace the CF card.Remove power from meter and reseat communications card. Apply power.


12 Glossary

9’s of AvailabilityA measurement used to show the availability of service. The 9’s translate into how much downtime is allowed per year. 90.0000% = 37 days99.0000% = 3.7 days99.9000% = 8.8 hours99.9900% = 53 minutes99.9990% = 5.3 minutes99.9999% = 32 seconds

Apparent PowerFor sinusoidal quantities in either single-phase or polyphase circuits, apparent power is the square root of the sum of the squares of the active and reactive powers.

AWGAmerican Wire Gauge. Standard wire-cross section area.

CBEMA FactorA transformer harmonic derating factor (THDF) defined as a pure sine wave’s crest factor (1.4141) divided by the mea-sured crest factor.

Crest FactorRatio of peak current to rms current. A pure sine wave has a crest factor of 1.414.

CT (Current Transformer) An instrument transformer that is intended to have its primary winding connected in series with the conductor carrying the current to be measured or controlled.

DemandThe average value of power or a related quantity over a specified interval of time.

dv/dtDelta voltage divided by delta time.

FlickerA variation of input voltage, either magnitude or frequency, sufficient in duration to allow visual observation of a change in electric light source intensity. See EN 61000-4-15 for details. Fourier Coefficients

Fourier Series A single-valued periodic function (that fulfills certain mathematical con-ditions) may be represented by a Fourier series as follows:Note: 0.5A0 is the average of a periodic function f(x) over one primitive period.

12 GLOSSARY


12 Glossary

GatewayA dedicated computer that attaches to two or more networks and routes packets from one to the other. In networking, a device that connects two systems that use different protocols.

GPSGlobal positioning system.

HarmonicThe components of the harmonic content as expressed in terms of the order and rms values of the Fourier series terms, describing the periodic function. Ia, Ib, IcPhase currents for phases a, b and c respectively.

IMPACCTM

Standard Cutler-Hammer Integrated Monitoring, Protection And Control Communications protocol definition for communi-cation on the INCOM network.

INCOMTM

Cutler-Hammer INdustrial COMmunications network.

K-FactorA derating factor related to the sum of the squares of har-monic current times the squares of their harmonic numbers (multiples of the fundamental).

kVA (Kilovolt-Ampere)One that designates the input kVA or volt-amperes at rated primary voltage with the secondary terminal short-circuited. kVAhKilovolt-ampere hour.

kVAh Kilovolt-ampere reactive.

kvarhKilovolt amps reactive hours.

kWKilowatt.

kWhKilowatt hour.

LagThe phase delay in current with respect to voltage.

Load ProfileThe magnitude and duration of loads applied in a prescribed time sequence, including the transient and steady-state char-acteristics of the individual loads. The recording, storage and analysis of consumption data over a period of time for a particular installation.

Load Shed The process of deliberately removing preselected loads from a power system in response to an abnormal condition in order to maintain the integrity of the system.

mAMilliAmpere.

mVMilliVolt.

Maximum DemandSee Peak Demand.

ModbusA popular industrial communication protocol.

MVARMegavolt amperes reactive.

MVARhMegavolt amperes reactive hours.

MWhMegawatt hours.

NTPNetwork time protocol.

Peak DemandThe greatest of all the demands that have occurred during a specified period of time; determined by measurement over a prescribed time interval.

PFASee, “Power factor”, Apparent.


12 Glossary

PFDSee, “Power factor”, Displacement. Also known as “True Power Factor”.

Phasor DiagramA diagram showing the relationships of as many of the follow-ing phasor quantities as are neces-sary: armature current, armature voltages, the direct and quadrature axes, armature flux linkages due to armature and field winding currents, mag-netomotive forces due to armature and field winding currents, and the various components of air-gap flux.

PT (Potential Transformer)An instrument transformer that is intended to have its primary winding connected in shunt with a power-supply circuit, the voltage of which is to be measured or controlled.

Power Factor A ratio of fundamental (50/60Hz) active power to apparent power (Fundamental watts to Funda-mental VA).

Power Factor, ApparentThe ratio of the active power of the total rms, in watts, to the apparent power of the total rms, in volt-amperes. This is also know as True Power Factor.

Power Factor, DisplacementThe ratio of the active power of the fundamental wave, in watts, to the apparent power of the fundamental wave, in volt-amperes.

Power QualityThe concept of powering and grounding electronic equipment in a manner that is suitable to the operation of the equipment and compatible with the premise wiring system and other connected equipment.

Pulse InitiatorAny device, mechanical or electrical, used with a meter to initiate pulses, the number of which are proportional to the quantity being measured. It may include an external amplifier or auxiliary relay or both.

Reactive PowerFor sinusoidal quantities in a two-wire circuit, reactive power is the product of the voltage, the current, and the sine of the phase angle between them. For nonsinusoidal quantities, it is the sum of all harmonic components, each determined as above. In a polyphase circuit, it is the sum of the reactive

powers of the individual phases.

RJ-11A six-pin modular telephone plug. Also called a permissive connection, an RJ-11 plug is generally used on two-wire circuits, but can be used on four-wire circuits.

RJ-45An eight-pin modular telephone plug. Also called a program-mable connection, an RJ-45 plug is generally used on four-wire circuits, but can be used on eight-wire circuits such as Ethernet.

rms (root mean squared)The effective value, or the value associated with joule heat-ing, of a periodic electromagnetic wave. The rms value is obtained by taking the square root of the mean of the squared value of a function.

RS-232 An EIA standard for asynchronous serial data communica-tions between terminal devices, such as printers, computers and communications equipment, such as modems. This stan-dard defines a 25-pin connector and certain signal character-istics for interfacing computer equip-ment.

SagA decrease in rms voltage at the power frequency for dura-tions of 0.5 cycle to 1 minute. A sag lasting longer than one minute is typically called undervoltage.

Swell An increase in rms voltage at the power fre-quency for dura-tions from 0.5 cycles to 1 minute. A swell lasting longer than one minute is typically called overvoltage.

TDD (Total Demand Distortion)Within the PowerXpert this is the ratio express as a precent of the rms value of the ac signal after rfundamental component is removed and interharmonic components are ignored, to the rated current (CT primary).

%TDD = 100 X CT Primary (Σ ) /85Cn2

n=2

1/2


12 Glossary

THD (Total Harmonic Distortion)The rms value of the ac signal after the fundamental compo-nent is removed and inter-harmonic components are ignored. Expressed as a precent, it is the ratio of the harmonic distor-tion to the rms value of the fundamental.

THD =%THD = X 100

TriggerTo cause a device to change state or to perform some other operation. A signal that causes a circuit or device to change state. VA, VB, VCPhase voltages for phases a, b and c respectively.

VAB, VBC, VCALine-to-line voltage between phase a & b, phase b & c, phase c & a respectively.

VT (Voltage Terminals)An instrument transformer designed for use in the measure-ment or control of voltage. Its primary winding is connected across the supply circuit.

Waveform DataThe numeric oscillographic values that may be captured. A manifestation or representation or visualization of a wave, pulse or transition (graph, plot, equation(s), table of coordi-nate or statistical data).

NOTE: Some of the information provided within these defini-tions have been extracted from The Authoritative Dictionary of IEEE Standard Terms Seventh Edition.

THDC1(Σ )

85Cn2

n=2

1/2


A MODBUS Communication

A MODBUS COMMUNICATION

A.1. Modbus Register Mapping

The Power Xpert Meter platform supports many standard buffers; however, it has extend-ed functionality such that complete new sets of registers are required.

A.2. Register 2001 (Invalid Object Access Configuration)

Register number 2001 is used to configure the product to respond to a group of data ob-jects, of which some objects are invalid within that group.When set to zero (default), the product will respond to a group of objects with data contained in the valid objects of the group along with 000016 data contained in the in-valid objects (or an invalid number, if available: for example floating point value NaN = 7FF2000016). This allows access to a block of registers using a single read command, of which some are not implemented in that block, rather than multiple read commands, which contain only implemented registers. The application is thus responsible for selecting the implemented registers. The starting register number must be a valid object. If the starting register number accesses an invalid object, the illegal data object exception code 02 will be issued, regardless of this configuration setting.When set to non zero, any attempt to access a group of data objects, which contain an invalid object will result in an illegal data object exception code 02.

A.3. Register 2002 (Floating-Point Data Register Configuration)

Register number 2002 is used to configure the 32 bit IEEE floating point word order. When set to zero (default), the floating point high-order 16 bit word is placed first in the Modbus register (x) followed by the low order 16 bit word in the next Modbus register space (x+1). The resulting transmission order is 3rd byte, 2nd byte, 1st byte and lastly 0th byte, with bit 24 transmitted first.When non zero, the floating-point low order 16 bit word is first in the Modbus register space.

A.4. Register 2003 (Fixed-Point Data Multi-Register Configuration)

Register number 2003 is used to configure the 32 bit and 64 bit fixed point word order (including the 64 bit extended energy objects).When set to zero (default), the fixed point multi-register high order 16 bit word is placed first in the Modbus register (x) followed by the next lower order 16 bit word in the next Modbus register space (x+1) and so forth. For 32 bit objects the resulting transmission order is 3rd byte, 2nd byte, 1st byte and lastly 0th byte, with bit 24 transmitted first. For 64 bit objects the resulting transmission order is 7th byte, 6th byte, 5th byte, 4th byte, 3rd byte, 2nd byte, 1st byte and lastly 0th byte, with bit 56 transmitted first.When non zero, the fixed-point low order 16 bit word is first in the Modbus register space.



A.5. Register 2901 (Controls – Modbus RTU)

BYTE2 BYTE1 BYTE0 Standard Control Definitions (BYTE3=0)0 0 4 Reset peak demand (kW, kvar, kVA, Amps)0 0 10H Reset device software (reboot)0 0 40H Reset (synchronize) demand windows0 1 4 Reset all min/max values 0 1 6 Reset discrete input counters3 0 1 Capture waveform3 0 3 Reset Com Port statistics3 0 4 Acknowledge triggered events (clear unread events

flag from status)4 1 X Activate relay output #X (0-2) for relays 1-3, respec-

tively4 2 X De-activate relay output #X (0-2) for relays 1-3,

respectively

A.6. Register 2921 (Time/Date)

The present device time can be read from these registers. A new time can be written to these registers and becomes an active clock. This is intended to represent the local time; however, if the zone offset is zero, the net effect is UTC (GMT).

Definition Register Number(decimal)

Data Range(decimal)

Month 2921 1 - 12Day 2922 1 - 31Year 2923 00-99Day Of Week 2924 1=Sunday...7=SaturdayHour 2925 0 – 23Minute 2926 0 – 59Second 2927 0 – 591/100th Second 2928 0 – 99

A.7. Register 4607, 4719 (duplicate addr) (ProductID) {0x0000200B}

Where:D5-D0=>Division Code=8; V3-V0 =>ComVersion=0; P5-P0 =>Product ID=11 (0xB)

126E 126FBits Bits Bits Bits31……24 23……16 15……8 7……0xxxxxxxx xxxxxxxx P5 | P4 | P3 | P2 | P1 | P0 | V3 | V2 V1 | V0 | D5 | D4 | D3 | D2 | D1 | D0



A.8. Register 4609 (Product Status)

P7 P6 P5 P4 P3 P2 P1 P0Hi Byte Lo Byte

Secondary Status CodePrimary Status Code

S7 S6 S5 S4 S3 P2 S1 S0

Primary Status Code

Primary Status Definition Secondary Status Code

Secondary Status Definition

4 Alarmed 1 Not Applicable4 Alarmed 2 Multiple Causes9 Operational 7 Powered Up

A.9. Register 4610 (Cause of Status)

0 0 0 0 C10 C9 C8

Hi Byte Lo Byte

Cause of Status Code

C7 C6 C5 C4 C3 C2 C1 C0

Change Notification Flag=0

0

Code Reason for Status Definition Code Reason for Status Definition0 Unknown 26 Power Demand 1 Normal operating mode 27 VA Demand11 Over Voltage 28 Var Demand12 Under Voltage 29 Current Demand15 Under Frequency 30 Total Harmonic Distortion16 Over Frequency 42 Multiple causes19 Apparent Power Factor 65 Reverse Power20 Displacement Power Factor 117 Voltage Sag23 Watt 118 Voltage Swell24 VA 142 Voltage Transient25 Var



A.10. Registers 4611-6332 (Real-Time Measured Values)

See Appendix B for detailed listing.

A.11. Register 11000+ (Real-Time and Historic Meter Data)

See Appendix B.

A.12. Types of Data

FLOATING-POINT (IEEE-754)

Power Xpert Meter makes extensive use of the IEEE-754 floating-point format for real-time and historic data. The standard representation requires a 32-bit word. The first bit is the sign bit, S, the next eight bits are the exponent bits, E, and the final 23 bits are the fraction F: S EEEEEEEE FFFFFFFFFFFFFFFFFFFFFFF

The value represented by the word may be determined as follows: • If E=255 and F is nonzero, then V=NaN (“Not a number”) • If E=255 and F is zero and S is 1, then V=-Infinity • If E=255 and F is zero and S is 0, then V=Infinity • If 0<E<255 then V=(-1) S * 2 (E-127) * (1.F) where 1.F is intended to represent the binary number created by prefixing F with an implicit leading 1 and a binary point.

• If E=0 and F is nonzero, then V=(-1) S * 2 (-126) * (0.F). [un-normalized value]

ENERGY FORMAT (64-BIT)

Energies are represented in a 64-bit format that includes a multiplier (2MantissaMultiplier) for scaling and engineering units (10EngineeringUnits) . If energy were merely kiloWatt-hours, the MantissaMultiplier equals 0 and Engineering Units equal 3. For further system simplicity, these should be constants such that the ModBus master does not need to repetitively read them.

LIST OF TRIGGER EVENTS

Starting at Reigster 18620 is a list of the 20 ost recent triggered events. 32-bit EventIDTimestamp UTC/GMT)Cause (see Register 4610 for definitions)Param 1, Param 2, IEEE floating-point values that are related to the event-if applicable.)

EVENT LOG

Starting at Register 29000 is a list of the 20 most recent logs. EventID (32 bit)Timestamp (UTC/GMT)Number of ASCII characters in logged ddescription (16 bit)Logged Description (ADCII string of up to 150 characters)



GENERAL FORMAT (1 SCALING REGISTER, 3 MANTISSA REGISTERS)

EEEEEEEEMMMMMMMMmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm-mmmmmmmmmmmmmmm

FORMAT FOR KWH/KVARH/KVAH

0000000000000011mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm-mmmmmmmmmmm

FORMAT FOR MWH/MVARH/MVAH

0000000000000110mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm-mmmmmmmmmmm

TIMESTAMP (UTC)

Definition Data Range(decimal)Month 1 - 12Day 1 - 31Year Hour 0 – 23Minute 0 – 59Millisecond 0 – 59999


B Standard & Extended Modbus Register Maps

B STANDARD & EXTENDED MODBUS REGISTER MAPS

B.1. Standard Modbus Register Map

Mod

bus

Reg

-is

ter

Hex

Mod

bus

Reg

iste

r

Description TypeId Units Reg

iste

r C

ount

2001 07D0 Invalid Object Access setting Uint16 Encoded 12002 07D1 Floating-Point Word Order setting Uint16 Encoded 12003 07D2 Fixed-Point Word Order setting Uint16 Encoded 1

2004 07D3Subnetwork Routing Mode (see chapter 2 for de-scription of mode settings) Uint16 Encoded 1

2005 07D4 Subnetwork Timeout Milliseconds Uint16 ms 12006 07D5 Subnetwork Retry Count Uint16 Encoded 12901 0B54 Slave Action Uint16 Encoded 32921 0B68 Time (MM/DD/YY day HH:MM:SS 100th) Uint16 Misc 84607 11FE Product ID (constant, initially 0x2C08) Uint32 24609 1200 Primary/Secondary Status Uint16 Encoded 14610 1201 Cause-Of-Status Uint16 Encoded 14611 1202 IA Float Amps 24613 1204 IB Float Amps 24615 1206 IC Float Amps 24617 1208 IG Float Amps 24619 120A IN Float Amps 24621 120C Iavg Float Amps 24623 120E VAB Float Volts 24625 1210 VBC Float Volts 24627 1212 VCA Float Volts 24629 1214 VLLavg Float Volts 24631 1216 VAN Float Volts 24633 1218 VBN Float Volts 24635 121A VCN Float Volts 24637 121C VLNavg Float Volts 24639 121E VNG Float Volts 2

4651 122A Real Power (Watts) Float Watts 24653 122C Reactive Power (VAr) Float VAr 24655 122E Apparent Power (VA) Float VA 24657 1230 PFd [Displacement Power Factor] Float 24659 1232 PFa [Apparent\True Power Factor] Float 2


B Standard & Extended Modbus Register Maps M

odbu

s R

eg-

iste

r

Hex

Mod

bus

Reg

iste

rDescription TypeId Units R

egis

ter

Cou

nt

4661 1234 Frequency Float Hz 2

4663 1236K-factor (not supported in PXM 4000 prior to firm-ware 12.x.x) Float 2

4665 1238Transformer Harmonic Derating Factor (sqrt2/Crest-Factor) Float 2

4667 123A Phase A Watts Float Watts 24669 123C Phase B Watts Float Watts 24671 123E Phase C Watts Float Watts 24673 1240 Phase A VAr Float VAr 24675 1242 Phase B VAr Float VAr 24677 1244 Phase C VAr Float VAr 24679 1246 Phase A VA Float VA 24681 1248 Phase B VA Float VA 24683 124A Phase C VA Float VA 24685 124C Phase A PFd [Displacement Power Factor] Float 24687 124E Phase B PFd Float 24689 1250 Phase C PFd Float 24691 1252 Phase A PFa [Apparent\True Power Factor] Float 24693 1254 Phase B PFa Float 24695 1256 Phase C PFa Float 2

4699 125A Source1 VAB (AUX) Float Volts 24701 125C Source1 VBC (AUX) Float Volts 24703 125E Source1 VCA (AUX) Float Volts 24705 1260 Freq (same as 4661) Float Hz 24719 126E ProductID (same as 4607) Uint32 2

4819 12D2 Phase A Direct (V) Float Volts 24821 12D4 Phase A Quadrature (V) Float Volts 24823 12D6 Phase B Direct (V) Float Volts 24825 12D8 Phase B Quadrature (V) Float Volts 24827 12DA Phase C Direct (V) Float Volts 24829 12DC Phase C Quadrature (V) Float Volts 2

4831 12DEPositive Sequence Direct (V) (not supported in PXM 4000) Float Volts 2

4833 12E0Positive Sequence Quadrature (V) (not supported in PXM 4000) Float Volts 2

6305 18A0 Forward Wh Energy Wh 46309 18A4 Reverse Wh Energy Wh 46313 18A8 Sum Total Wh Energy Wh 4



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6317 18AC Delivered/Leading Varh Energy VArh 46321 18B0 Received/Lagging Varh Energy VArh 46325 18B4 Net Varh Energy VArh 46329 18B8 Vah Energy Vah 4

B.2. Extended Modbus Register Map

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10000 270F Basic Settings Settings Misc Misc TBD11000 2AF7 Miscellaneous EventCount Uint32 EventCount 211002 2AF9 NinesOfAvailability\Performance Float Percentage 211004 2AFB SystemFrequency Float Hertz 211006 2AFD Current Ig200 [200ms rms current] Float Amps 211008 2AFF In200 Float Amps 211010 2B01 Ia200 Float Amps 211012 2B03 Ib200 Float Amps 211014 2B05 Ic200 Float Amps 211016 2B07 Iavg200 Float Amps 211018 2B09 Voltage Vlnavg200 [200ms rms voltage] Float Volts 211020 2B0B Vng200 Float Volts 211022 2B0D VllavgAUX_200 Float Volts 211024 2B0F VabAUX_200 Float Volts 211026 2B11 VbcAUX_200 Float Volts 211028 2B13 VcaAUX_200 Float Volts 211030 2B15 Van200 Float Volts 211032 2B17 Vab200 Float Volts 211034 2B19 Vbn200 Float Volts 211036 2B1B Vbc200 Float Volts 211038 2B1D Vcn200 Float Volts 211040 2B1F Vca200 Float Volts 211042 2B21 Vllavg200 Float Volts 211044 2B23 Apparent\True PowerFactor PhaseA Float 211046 2B25 PhaseB Float 2



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11048 2B27 PhaseC Float 211050 2B29 System Float 211052 2B2B RealForwardEnergy RateA Energy kWh 411056 2B2F RateB Energy kWh 411060 2B33 RateC Energy kWh 411064 2B37 RateD Energy kWh 411068 2B3B RTP Energy kWh 411072 2B3F Total Energy kWh 411076 2B43 RealReverseEnergy RateA Energy kWh 411080 2B47 RateB Energy kWh 411084 2B4B RateC Energy kWh 411088 2B4F RateD Energy kWh 411092 2B53 RTP Energy kWh 411096 2B57 Total Energy kWh 411100 2B5B RealNetEnergy RateA Energy kWh 411104 2B5F RateB Energy kWh 411108 2B63 RateC Energy kWh 411112 2B67 RateD Energy kWh 411116 2B6B RTP Energy kWh 411120 2B6F Total Energy kWh 411124 2B73 RealTotalEnergy RateA Energy kWh 411128 2B77 RateB Energy kWh 411132 2B7B RateC Energy kWh 411136 2B7F RateD Energy kWh 411140 2B83 RTP Energy kWh 411144 2B87 Total Energy kWh 411148 2B8B ApparentEnergy (kVAh) RateA Energy kVAh 411152 2B8F RateB Energy kVAh 411156 2B93 RateC Energy kVAh 411160 2B97 RateD Energy kVAh 411164 2B9B RTP Energy kVAh 411168 2B9F Total Energy kVAh 411172 2BA3 ReactiveDeliveredEnergy RateA Energy kVArh 411176 2BA7 RateB Energy kVArh 411180 2BAB RateC Energy kVArh 411184 2BAF RateD Energy kVArh 411188 2BB3 RTP Energy kVArh 411192 2BB7 Total Energy kVArh 411196 2BBB ReactiveReceivedEnergy RateA Energy kVArh 411200 2BBF RateB Energy kVArh 4



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11204 2BC3 RateC Energy kVArh 411208 2BC7 RateD Energy kVArh 411212 2BCB RTP Energy kVArh 411216 2BCF Total Energy kVArh 411220 2BD3 ReactiveNetEnergy RateA Energy kVArh 411224 2BD7 RateB Energy kVArh 411228 2BDB RateC Energy kVArh 411232 2BDF RateD Energy kVArh 411236 2BE3 RTP Energy kVArh 411240 2BE7 Total Energy kVArh 411244 2BEB ReactiveTotalEnergy RateA Energy kVArh 411248 2BEF RateB Energy kVArh 411252 2BF3 RateC Energy kVArh 411256 2BF7 RateD Energy kVArh 411260 2BFB RTP Energy kVArh 411264 2BFF Total Energy kVArh 411268 2C03 CrestFactor PhaseA Float 211270 2C05 PhaseB Float 211272 2C07 PhaseC Float 211274 2C09 SystemMaximum Float 2

11276 2C0BITIC Factor

PhaseA Float 211278 2C0D PhaseB Float 211280 2C0F PhaseC Float 211282 2C11 SystemMinimum Float 2

11284 2C13FlickerPerceptibility (not supported in PXM 4000) PhaseAtoNeutral Float 2

11286 2C15 (not supported in PXM 4000) PhaseAtoPhaseB Float 211288 2C17 (not supported in PXM 4000) PhaseBtoNeutral Float 211290 2C19 (not supported in PXM 4000) PhaseBtoPhaseC Float 211292 2C1B (not supported in PXM 4000) PhaseCtoNeutral Float 211294 2C1D (not supported in PXM 4000) PhaseCtoPhaseA Float 2

11296 2C1FShortTermFlickerPerceptibility (not supported in PXM 4000) PhaseAtoNeutral Float 2

11298 2C21 (not supported in PXM 4000) PhaseAtoPhaseB Float 211300 2C23 (not supported in PXM 4000) PhaseBtoNeutral Float 211302 2C25 (not supported in PXM 4000) PhaseBtoPhaseC Float 211304 2C27 (not supported in PXM 4000) PhaseCtoNeutral Float 211306 2C29 (not supported in PXM 4000) PhaseCtoPhaseA Float 2

11308 2C2BK-Factor

PhaseA Float 211310 2C2D PhaseB Float 2



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11312 2C2F PhaseC Float 211314 2C31 SystemMaximum Float 2

11316 2C33EvenHarmonic DistortionMagnitude (not supported in PXM 4000) NeutralCurrent Float Amps 2

11318 2C35 (not supported in PXM 4000) AUX PhaseAtoBVoltage Float Volts 211320 2C37 (not supported in PXM 4000) AUX PhaseBtoCVoltage Float Volts 211322 2C39 (not supported in PXM 4000) AUX PhaseCtoAVoltage Float Volts 211324 2C3B (not supported in PXM 4000) PhaseACurrent Float Amps 211326 2C3D (not supported in PXM 4000) PhaseAtoBVoltage Float Volts 211328 2C3F (not supported in PXM 4000) PhaseAtoNeutralVoltage Float Volts 211330 2C41 (not supported in PXM 4000) PhaseBCurrent Float Amps 211332 2C43 (not supported in PXM 4000) PhaseBtoCVoltage Float Volts 211334 2C45 (not supported in PXM 4000) PhaseBtoNeutralVoltage Float Volts 211336 2C47 (not supported in PXM 4000) PhaseCCurrent Float Amps 211338 2C49 (not supported in PXM 4000) PhaseCtoAVoltage Float Volts 211340 2C4B (not supported in PXM 4000) PhaseCtoNeutralVoltage Float Volts 2

11342 2C4DOddHarmonic DistortionMagnitude (not supported in PXM 4000) NeutralCurrent Float Amps 2

11344 2C4F (not supported in PXM 4000) AUX PhaseAtoBVoltage Float Volts 211346 2C51 (not supported in PXM 4000) AUX PhaseBtoCVoltage Float Volts 211348 2C53 (not supported in PXM 4000) AUX PhaseCtoAVoltage Float Volts 211350 2C55 (not supported in PXM 4000) PhaseACurrent Float Amps 211352 2C57 (not supported in PXM 4000) PhaseAtoBVoltage Float Volts 211354 2C59 (not supported in PXM 4000) PhaseAtoNeutralVoltage Float Volts 211356 2C5B (not supported in PXM 4000) PhaseBCurrent Float Amps 211358 2C5D (not supported in PXM 4000) PhaseBtoCVoltage Float Volts 211360 2C5F (not supported in PXM 4000) PhaseBtoNeutralVoltage Float Volts 211362 2C61 (not supported in PXM 4000) PhaseCCurrent Float Amps 211364 2C63 (not supported in PXM 4000) PhaseCtoAVoltage Float Volts 211366 2C65 (not supported in PXM 4000) PhaseCtoNeutralVoltage Float Volts 2

11368 2C67InterHarmonic DistortionMagnitude (not supported in PXM 4000) NeutralCurrent Float Amps 2

11370 2C69 (not supported in PXM 4000) AUX PhaseAtoBVoltage Float Volts 211372 2C6B (not supported in PXM 4000) AUX PhaseBtoCVoltage Float Volts 211374 2C6D (not supported in PXM 4000) AUX PhaseCtoAVoltage Float Volts 211376 2C6F (not supported in PXM 4000) PhaseACurrent Float Amps 211378 2C71 (not supported in PXM 4000) PhaseAtoBVoltage Float Volts 211380 2C73 (not supported in PXM 4000) PhaseAtoNeutralVoltage Float Volts 211382 2C75 (not supported in PXM 4000) PhaseBCurrent Float Amps 211384 2C77 (not supported in PXM 4000) PhaseBtoCVoltage Float Volts 211386 2C79 (not supported in PXM 4000) PhaseBtoNeutralVoltage Float Volts 2



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11388 2C7B (not supported in PXM 4000) PhaseCCurrent Float Amps 211390 2C7D (not supported in PXM 4000) PhaseCtoAVoltage Float Volts 211392 2C7F (not supported in PXM 4000) PhaseCtoNeutralVoltage Float Volts 211394 2C81 TotalHarmonic DistortionMagnitude NeutralCurrent Float Amps 211396 2C83 AUX PhaseAtoBVoltage Float Volts 211398 2C85 AUX PhaseBtoCVoltage Float Volts 211400 2C87 AUX PhaseCtoAVoltage Float Volts 211402 2C89 PhaseACurrent Float Amps 211404 2C8B PhaseAtoBVoltage Float Volts 211406 2C8D PhaseAtoNeutralVoltage Float Volts 211408 2C8F PhaseBCurrent Float Amps 211410 2C91 PhaseBtoCVoltage Float Volts 211412 2C93 PhaseBtoNeutralVoltage Float Volts 211414 2C95 PhaseCCurrent Float Amps 211416 2C97 PhaseCtoAVoltage Float Volts 211418 2C99 PhaseCtoNeutralVoltage Float Volts 211420 2C9B DisplacementPowerFactor DPFa Float 211422 2C9D DPFb Float 211424 2C9F DPFc Float 211426 2CA1 DPFsys Float 211428 2CA3 Apparent Power Sa Float kVA 211430 2CA5 Sb Float kVA 211432 2CA7 Sc Float kVA 211434 2CA9 Stotal Float kVA 211436 2CAB Reactive Power Qa Float kvar 211438 2CAD Qb Float kvar 211440 2CAF Qc Float kvar 211442 2CB1 Qsys Float kvar 211444 2CB3 Real Power Pa Float kW 211446 2CB5 Pb Float kW 211448 2CB7 Pc Float kW 211450 2CB9 Ptotal Float kW 211452 2CBB CurrentPhaseAngle Neutral Float Degrees 211454 2CBD PhaseA Float Degrees 211456 2CBF PhaseB Float Degrees 211458 2CC1 PhaseC Float Degrees 211460 2CC3 VoltagePhaseAngle Van Float Degrees 211462 2CC5 Vbn Float Degrees 211464 2CC7 Vcn Float Degrees 211466 2CC9 Vab Float Degrees 2



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11468 2CCB Vbc Float Degrees 211470 2CCD Vca Float Degrees 211472 2CCF CurrentPhasor PhasorIg Complex Amps 411476 2CD3 PhasorIn Complex Amps 411480 2CD7 PhasorIa Complex Amps 411484 2CDB PhasorIb Complex Amps 411488 2CDF PhasorIc Complex Amps 411492 2CE3 VoltagePhasor PhasorVan Complex Volts 411496 2CE7 PhasorVbn Complex Volts 411500 2CEB PhasorVcn Complex Volts 411504 2CEF PhasorVab Complex Volts 411508 2CF3 PhasorVbc Complex Volts 411512 2CF7 PhasorVca Complex Volts 4

11516 2CFBSymmetric Current Component (not supported in PXM 4000) PosSeqI Complex Amps 4

11520 2CFF (not supported in PXM 4000) NegSeqI Complex Amps 411524 2D03 (not supported in PXM 4000) ZeroSeqI Complex Amps 4

11528 2D07SymmetricAUX VoltageComponent (not supported in PXM 4000) PosSeqVAUX Complex Volts 4

11532 2D0B (not supported in PXM 4000) NegSeqVAUX Complex Volts 411536 2D0F (not supported in PXM 4000) ZeroSeqVAUX Complex Volts 4

11540 2D13SymmetricVoltage Component (not supported in PXM 4000) PosSeqV Complex Volts 4

11544 2D17 (not supported in PXM 4000) NegSeqV Complex Volts 411548 2D1B (not supported in PXM 4000) ZeroSeqV Complex Volts 4

2D1F LastMonthDemandCurrent PeakDmdRateA Float Amps 211554 2D21 PeakDmdRateB Float 211556 2D23 PeakDmdRateC Float 211558 2D25 PeakDmdRateD Float 211560 2D27 PeakDmdRateTot Float 211562 2D29 PeakDmdRateRTP Float 211566 2D2D LastMonthDemand CurrentDate PeakDmdRateA Date Date 611572 2D33 PeakDmdRateB Date 611578 2D39 PeakDmdRateC Date 611584 2D3F PeakDmdRateD Date 611590 2D45 PeakDmdRateTot Date 611596 2D4B PeakDmdRateRTP Date 611636 2D73 LastMonthFwdReal DemandPower PeakDmdRateA Float Watts 211638 2D75 PeakDmdRateB Float 211640 2D77 PeakDmdRateC Float 211642 2D79 PeakDmdRateD Float 2



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11644 2D7B PeakDmdRateTot Float 211646 2D7D PeakDmdRateRTP Float 2

11650 2D81LastMonthFwdReal DemandPower-Date PeakDmdRateA Date Date 6

11656 2D87 PeakDmdRateB Date 611662 2D8D PeakDmdRateC Date 611668 2D93 PeakDmdRateD Date 611674 2D99 PeakDmdRateTot Date 611680 2D9F PeakDmdRateRTP Date 611720 2DC7 LastMonthRevReal DemandPower PeakDmdRateA Float Watts 211722 2DC9 PeakDmdRateB Float 211724 2DCB PeakDmdRateC Float 211726 2DCD PeakDmdRateD Float 211728 2DCF PeakDmdRateTot Float 211730 2DD1 PeakDmdRateRTP Float 2

11734 2DD5LastMonthRevReal DemandPower-Date PeakDmdRateA Date Date 6

11740 2DDB PeakDmdRateB Date 611746 2DE1 PeakDmdRateC Date 611752 2DE7 PeakDmdRateD Date 611758 2DED PeakDmdRateTot Date 611764 2DF3 PeakDmdRateRTP Date 611804 2E1B LastMonthNetReal DemandPower PeakDmdRateA Float Watts 211806 2E1D PeakDmdRateB Float 211808 2E1F PeakDmdRateC Float 211810 2E21 PeakDmdRateD Float 211812 2E23 PeakDmdRateTot Float 211814 2E25 PeakDmdRateRTP Float 2

11818 2E29LastMonthNetReal DemandPower-Date PeakDmdRateA Date Date 6

11824 2E2F PeakDmdRateB Date 611830 2E35 PeakDmdRateC Date 611836 2E3B PeakDmdRateD Date 611842 2E41 PeakDmdRateTot Date 611848 2E47 PeakDmdRateRTP Date 611888 2E6F LastMonthSumReal DemandPower PeakDmdRateA Float Watts 211890 2E71 PeakDmdRateB Float 211892 2E73 PeakDmdRateC Float 211894 2E75 PeakDmdRateD Float 211896 2E77 PeakDmdRateTot Float 211898 2E79 PeakDmdRateRTP Float 2



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11902 2E7DLastMonthSumReal DemandPower-Date PeakDmdRateA Date Date 6

11908 2E83 PeakDmdRateB Date 611914 2E89 PeakDmdRateC Date 611920 2E8F PeakDmdRateD Date 611926 2E95 PeakDmdRateTot Date 611932 2E9B PeakDmdRateRTP Date 6

11972 2EC3LastMonthDeliveredReactive Deman-dPower PeakDmdRateA Float var 2

11974 2EC5 PeakDmdRateB Float 211976 2EC7 PeakDmdRateC Float 211978 2EC9 PeakDmdRateD Float 211980 2ECB PeakDmdRateTot Float 211982 2ECD PeakDmdRateRTP Float 2

11986 2ED1LastMonthDeliveredReactive Deman-dPowerDate PeakDmdRateA Date Date 6

11992 2ED7 PeakDmdRateB Date 611998 2EDD PeakDmdRateC Date 612004 2EE3 PeakDmdRateD Date 612010 2EE9 PeakDmdRateTot Date 612016 2EEF PeakDmdRateRTP Date 6

12056 2F17LastMonthReceivedReactive De-mandPower PeakDmdRateA Float var 2

12058 2F19 PeakDmdRateB Float 212060 2F1B PeakDmdRateC Float 212062 2F1D PeakDmdRateD Float 212064 2F1F PeakDmdRateTot Float 212066 2F21 PeakDmdRateRTP Float 2

12070 2F25LastMonthReceivedReactive De-mandPowerDate PeakDmdRateA Date Date 6

12076 2F2B PeakDmdRateB Date 612082 2F31 PeakDmdRateC Date 612088 2F37 PeakDmdRateD Date 612094 2F3D PeakDmdRateTot Date 612100 2F43 PeakDmdRateRTP Date 6

12140 2F6BLastMonthNetReactive Demand-Power PeakDmdRateA Float var 2

12142 2F6D PeakDmdRateB Float 212144 2F6F PeakDmdRateC Float 212146 2F71 PeakDmdRateD Float 212148 2F73 PeakDmdRateTot Float 212150 2F75 PeakDmdRateRTP Float 2



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12154 2F79LastMonthNetReactive DemandPow-erDate PeakDmdRateA Date Date 6

12160 2F7F PeakDmdRateB Date 612166 2F85 PeakDmdRateC Date 612172 2F8B PeakDmdRateD Date 612178 2F91 PeakDmdRateTot Date 612184 2F97 PeakDmdRateRTP Date 6

12224 2FBFLastMonthSumReactive Demand-Power PeakDmdRateA Float var 2

12226 2FC1 PeakDmdRateB Float 212228 2FC3 PeakDmdRateC Float 212230 2FC5 PeakDmdRateD Float 212232 2FC7 PeakDmdRateTot Float 212234 2FC9 PeakDmdRateRTP Float 2

12238 2FCDLastMonthSumReactive Demand-PowerDate PeakDmdRateA Date Date 6

12244 2FD3 PeakDmdRateB Date 612250 2FD9 PeakDmdRateC Date 612256 2FDF PeakDmdRateD Date 612262 2FE5 PeakDmdRateTot Date 612268 2FEB PeakDmdRateRTP Date 612308 3013 LastMonthApparent DemandPower PeakDmdRateA Float VA 212310 3015 PeakDmdRateB Float 212312 3017 PeakDmdRateC Float 212314 3019 PeakDmdRateD Float 212316 301B PeakDmdRateTot Float 212318 301D PeakDmdRateRTP Float 2

12322 3021LastMonthApparent DemandPower-Date PeakDmdRateA Date Date 6

12328 3027 PeakDmdRateB Date 612334 302D PeakDmdRateC Date 612340 3033 PeakDmdRateD Date 612346 3039 PeakDmdRateTot Date 612352 303F PeakDmdRateRTP Date 612392 3067 LastPeakDemandCurrent PeakDmdRateA Float Amps 212394 3069 PeakDmdRateB Float 212396 306B PeakDmdRateC Float 212398 306D PeakDmdRateD Float 212400 306F PeakDmdRateTot Float 212402 3071 PeakDmdRateRTP Float 212406 3075 LastPeakDemandCurrentDate PeakDmdRateA Date Date 6



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12412 307B PeakDmdRateB Date 612418 3081 PeakDmdRateC Date 612424 3087 PeakDmdRateD Date 612430 308D PeakDmdRateTot Date 612436 3093 PeakDmdRateRTP Date 612476 30BB LastPeakFwdReal DemandPower PeakDmdRateA Float Watts 212478 30BD PeakDmdRateB Float 212480 30BF PeakDmdRateC Float 212482 30C1 PeakDmdRateD Float 212484 30C3 PeakDmdRateTot Float 212486 30C5 PeakDmdRateRTP Float 2

12490 30C9LastPeakFwdReal DemandPower-Date PeakDmdRateA Date Date 6

12496 30CF PeakDmdRateB Date 612502 30D5 PeakDmdRateC Date 612508 30DB PeakDmdRateD Date 612514 30E1 PeakDmdRateTot Date 612520 30E7 PeakDmdRateRTP Date 612560 310F LastPeakRevReal DemandPower PeakDmdRateA Float Watts 212562 3111 PeakDmdRateB Float 212564 3113 PeakDmdRateC Float 212566 3115 PeakDmdRateD Float 212568 3117 PeakDmdRateTot Float 212570 3119 PeakDmdRateRTP Float 2

12574 311DLastPeakRevReal DemandPower-Date PeakDmdRateA Date Date 6

12580 3123 PeakDmdRateB Date 612586 3129 PeakDmdRateC Date 612592 312F PeakDmdRateD Date 612598 3135 PeakDmdRateTot Date 612604 313B PeakDmdRateRTP Date 612644 3163 LastPeakNetReal DemandPower PeakDmdRateA Float Watts 212646 3165 PeakDmdRateB Float 212648 3167 PeakDmdRateC Float 212650 3169 PeakDmdRateD Float 212652 316B PeakDmdRateTot Float 212654 316D PeakDmdRateRTP Float 212658 3171 LastPeakNetReal DemandPowerDatePeakDmdRateA Date Date 612664 3177 PeakDmdRateB Date 612670 317D PeakDmdRateC Date 612676 3183 PeakDmdRateD Date 6



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12682 3189 PeakDmdRateTot Date 612688 318F PeakDmdRateRTP Date 612728 31B7 LastPeakSumReal DemandPower PeakDmdRateA Float Watts 212730 31B9 PeakDmdRateB Float 212732 31BB PeakDmdRateC Float 212734 31BD PeakDmdRateD Float 212736 31BF PeakDmdRateTot Float 212738 31C1 PeakDmdRateRTP Float 2

12742 31C5LastPeakSumReal DemandPower-Date PeakDmdRateA Date Date 6

12748 31CB PeakDmdRateB Date 612754 31D1 PeakDmdRateC Date 612760 31D7 PeakDmdRateD Date 612766 31DD PeakDmdRateTot Date 612772 31E3 PeakDmdRateRTP Date 6

12812 320BLastPeakDeliveredReactive Demand-Power PeakDmdRateA Float var 2

12814 320D PeakDmdRateB Float 212816 320F PeakDmdRateC Float 212818 3211 PeakDmdRateD Float 212820 3213 PeakDmdRateTot Float 212822 3215 PeakDmdRateRTP Float 2

12826 3219LastPeakDeliveredReactive Demand-PowerDate PeakDmdRateA Date Date 6

12832 321F PeakDmdRateB Date 612838 3225 PeakDmdRateC Date 612844 322B PeakDmdRateD Date 612850 3231 PeakDmdRateTot Date 612856 3237 PeakDmdRateRTP Date 6

12896 325FLastPeakReceivedReactive Demand-Power PeakDmdRateA Float var 2

12898 3261 PeakDmdRateB Float 212900 3263 PeakDmdRateC Float 212902 3265 PeakDmdRateD Float 212904 3267 PeakDmdRateTot Float 212906 3269 PeakDmdRateRTP Float 2

12910 326DLastPeakReceivedReactive Demand-PowerDate PeakDmdRateA Date Date 6

12916 3273 PeakDmdRateB Date 612922 3279 PeakDmdRateC Date 612928 327F PeakDmdRateD Date 612934 3285 PeakDmdRateTot Date 6



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12940 328B PeakDmdRateRTP Date 612980 32B3 LastPeakNetReactive DemandPower PeakDmdRateA Float var 212982 32B5 PeakDmdRateB Float 212984 32B7 PeakDmdRateC Float 212986 32B9 PeakDmdRateD Float 212988 32BB PeakDmdRateTot Float 212990 32BD PeakDmdRateRTP Float 2

12994 32C1LastPeakNetReactive DemandPow-erDate PeakDmdRateA Date Date 6

13000 32C7 PeakDmdRateB Date 613006 32CD PeakDmdRateC Date 613012 32D3 PeakDmdRateD Date 613018 32D9 PeakDmdRateTot Date 613024 32DF PeakDmdRateRTP Date 6

13064 3307LastPeakSumReactive Demand-Power PeakDmdRateA Float var 2

13066 3309 PeakDmdRateB Float 213068 330B PeakDmdRateC Float 213070 330D PeakDmdRateD Float 213072 330F PeakDmdRateTot Float 213074 3311 PeakDmdRateRTP Float 2

13078 3315LastPeakSumReactive DemandPow-erDate PeakDmdRateA Date Date 6

13084 331B PeakDmdRateB Date 613090 3321 PeakDmdRateC Date 613096 3327 PeakDmdRateD Date 613102 332D PeakDmdRateTot Date 613108 3333 PeakDmdRateRTP Date 613148 335B LastPeakApparent DemandPower PeakDmdRateA Float VA 213150 335D PeakDmdRateB Float 213152 335F PeakDmdRateC Float 213154 3361 PeakDmdRateD Float 213156 3363 PeakDmdRateTot Float 213158 3365 PeakDmdRateRTP Float 2

13162 3369LastPeakApparent DemandPower-Date PeakDmdRateA Date Date 6

13168 336F PeakDmdRateB Date 613174 3375 PeakDmdRateC Date 613180 337B PeakDmdRateD Date 613186 3381 PeakDmdRateTot Date 613192 3387 PeakDmdRateRTP Date 6



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13232 33AF LastResetDemandCurrent PeakDmdRateA Float Amps 213234 33B1 PeakDmdRateB Float 213236 33B3 PeakDmdRateC Float 213238 33B5 PeakDmdRateD Float 213240 33B7 PeakDmdRateTot Float 213242 33B9 PeakDmdRateRTP Float 213246 33BD LastResetDemandCurrentDate PeakDmdRateA Date Date 613252 33C3 PeakDmdRateB Date 613258 33C9 PeakDmdRateC Date 613264 33CF PeakDmdRateD Date 613270 33D5 PeakDmdRateTot Date 613276 33DB PeakDmdRateRTP Date 613316 3403 LastResetFwdReal DemandPower PeakDmdRateA Float Watts 213318 3405 PeakDmdRateB Float 213320 3407 PeakDmdRateC Float 213322 3409 PeakDmdRateD Float 213324 340B PeakDmdRateTot Float 213326 340D PeakDmdRateRTP Float 2

13330 3411LastResetFwdReal DemandPower-Date PeakDmdRateA Date Date 6

13336 3417 PeakDmdRateB Date 613342 341D PeakDmdRateC Date 613348 3423 PeakDmdRateD Date 613354 3429 PeakDmdRateTot Date 613360 342F PeakDmdRateRTP Date 613372 343B LastResetFwdReal PowerAccum RateA Energy Wh 413376 343F RateB Energy 413380 3443 RateC Energy 413384 3447 RateD Energy 413388 344B RateTot Energy 413392 344F RateRTP Energy 413400 3457 LastResetRevReal DemandPower PeakDmdRateA Float Watts 213402 3459 PeakDmdRateB Float 213404 345B PeakDmdRateC Float 213406 345D PeakDmdRateD Float 213408 345F PeakDmdRateTot Float 213410 3461 PeakDmdRateRTP Float 2

13414 3465LastResetRevReal DemandPower-Date PeakDmdRateA Date Date 6

13420 346B PeakDmdRateB Date 613426 3471 PeakDmdRateC Date 6



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13432 3477 PeakDmdRateD Date 613438 347D PeakDmdRateTot Date 613444 3483 PeakDmdRateRTP Date 613456 348F LastResetRevReal PowerAccum RateA Energy Wh 413460 3493 RateB Energy 413464 3497 RateC Energy 413468 349B RateD Energy 413472 349F RateTot Energy 413476 34A3 RateRTP Energy 413484 34AB LastResetNetReal DemandPower PeakDmdRateA Float Watts 213486 34AD PeakDmdRateB Float 213488 34AF PeakDmdRateC Float 213490 34B1 PeakDmdRateD Float 213492 34B3 PeakDmdRateTot Float 213494 34B5 PeakDmdRateRTP Float 2

13498 34B9LastResetNetReal DemandPower-Date PeakDmdRateA Date Date 6

13504 34BF PeakDmdRateB Date 613510 34C5 PeakDmdRateC Date 613516 34CB PeakDmdRateD Date 613522 34D1 PeakDmdRateTot Date 613528 34D7 PeakDmdRateRTP Date 613540 34E3 LastResetNetReal PowerAccum RateA Energy Wh 413544 34E7 RateB Energy 413548 34EB RateC Energy 413552 34EF RateD Energy 413556 34F3 RateTot Energy 413560 34F7 RateRTP Energy 413568 34FF LastResetSumReal DemandPower PeakDmdRateA Float Watts 213570 3501 PeakDmdRateB Float 213572 3503 PeakDmdRateC Float 213574 3505 PeakDmdRateD Float 213576 3507 PeakDmdRateTot Float 213578 3509 PeakDmdRateRTP Float 2

13582 350DLastResetSumReal DemandPower-Date PeakDmdRateA Date Date 6

13588 3513 PeakDmdRateB Date 613594 3519 PeakDmdRateC Date 613600 351F PeakDmdRateD Date 613606 3525 PeakDmdRateTot Date 613612 352B PeakDmdRateRTP Date 613624 3537 LastResetSumReal PowerAccum RateA Energy Wh 4



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13628 353B RateB Energy 413632 353F RateC Energy 413636 3543 RateD Energy 413640 3547 RateTot Energy 413644 354B RateRTP Energy 4

13652 3553LastResetDeliveredReactive De-mandPower PeakDmdRateA Float var 2

13654 3555 PeakDmdRateB Float 213656 3557 PeakDmdRateC Float 213658 3559 PeakDmdRateD Float 213660 355B PeakDmdRateTot Float 213662 355D PeakDmdRateRTP Float 2

13666 3561LastResetDeliveredReactive De-mandPowerDate PeakDmdRateA Date Date 6

13672 3567 PeakDmdRateB Date 613678 356D PeakDmdRateC Date 613684 3573 PeakDmdRateD Date 613690 3579 PeakDmdRateTot Date 613696 357F PeakDmdRateRTP Date 6

13708 358BLastResetDeliveredReactive Power-Accum RateA Energy varh 4

13712 358F RateB Energy 413716 3593 RateC Energy 413720 3597 RateD Energy 413724 359B RateTot Energy 413728 359F RateRTP Energy 4

13736 35A7LastResetReceivedReactive Deman-dPower PeakDmdRateA Float var 2

13738 35A9 PeakDmdRateB Float 213740 35AB PeakDmdRateC Float 213742 35AD PeakDmdRateD Float 213744 35AF PeakDmdRateTot Float 213746 35B1 PeakDmdRateRTP Float 2

13750 35B5LastResetReceivedReactive De-mandPowerDate PeakDmdRateA Date Date 6

13756 35BB PeakDmdRateB Date 613762 35C1 PeakDmdRateC Date 613768 35C7 PeakDmdRateD Date 613774 35CD PeakDmdRateTot Date 613780 35D3 PeakDmdRateRTP Date 6

13792 35DFLastResetReceivedReactive Power-Accum RateA Energy varh 4

13796 35E3 RateB Energy 4



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13800 35E7 RateC Energy 413804 35EB RateD Energy 413808 35EF RateTot Energy 413812 35F3 RateRTP Energy 4

13820 35FBLastResetNetReactive Demand-Power PeakDmdRateA Float var 2

13822 35FD PeakDmdRateB Float 213824 35FF PeakDmdRateC Float 213826 3601 PeakDmdRateD Float 213828 3603 PeakDmdRateTot Float 213830 3605 PeakDmdRateRTP Float 2

13834 3609LastResetNetReactive DemandPow-erDate PeakDmdRateA Date Date 6

13840 360F PeakDmdRateB Date 613846 3615 PeakDmdRateC Date 613852 361B PeakDmdRateD Date 613858 3621 PeakDmdRateTot Date 613864 3627 PeakDmdRateRTP Date 613876 3633 LastResetNetReactive PowerAccum RateA Energy varh 413880 3637 RateB Energy 413884 363B RateC Energy 413888 363F RateD Energy 413892 3643 RateTot Energy 413896 3647 RateRTP Energy 4

13904 364FLastResetSumReactive Demand-Power PeakDmdRateA Float var 2

13906 3651 PeakDmdRateB Float 213908 3653 PeakDmdRateC Float 213910 3655 PeakDmdRateD Float 213912 3657 PeakDmdRateTot Float 213914 3659 PeakDmdRateRTP Float 2

13918 365DLastResetSumReactive DemandPow-erDate PeakDmdRateA Date Date 6

13924 3663 PeakDmdRateB Date 613930 3669 PeakDmdRateC Date 613936 366F PeakDmdRateD Date 613942 3675 PeakDmdRateTot Date 613948 367B PeakDmdRateRTP Date 613960 3687 LastResetSumReactive PowerAccum RateA Energy varh 413964 368B RateB Energy 413968 368F RateC Energy 4



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13972 3693 RateD Energy 413976 3697 RateTot Energy 413980 369B RateRTP Energy 413988 36A3 LastResetApparent DemandPower PeakDmdRateA Float VA 213990 36A5 PeakDmdRateB Float 213992 36A7 PeakDmdRateC Float 213994 36A9 PeakDmdRateD Float 213996 36AB PeakDmdRateTot Float 213998 36AD PeakDmdRateRTP Float 2

14002 36B1LastResetApparent DemandPower-Date PeakDmdRateA Date Date 6

14008 36B7 PeakDmdRateB Date 614014 36BD PeakDmdRateC Date 614020 36C3 PeakDmdRateD Date 614026 36C9 PeakDmdRateTot Date 614032 36CF PeakDmdRateRTP Date 6

14044 36DBLastResetApparent DemandPower-Accum RateA Energy VA h 4

14048 36DF RateB Energy 414052 36E3 RateC Energy 414056 36E7 RateD Energy 414060 36EB RateTot Energy 414064 36EF RateRTP Energy 4

14112 371FPresentDemand

eIavgDmd Float 214114 3721 WattFwdDmd Float 214116 3723 WattRevDmd Float 214118 3725 WattNetDmd Float 214120 3727 WattTotDmd Float 214122 3729 VarDeliveredDmd Float 214124 372B VarReceivedDmd Float 214126 372D VarNetDmd Float 214128 372F VarTotDmd Float 214130 3731 VADmd Float 2

14152 3747SagSwellCount (not supported in PXM 4000) SagLev1 Uint16 1

14153 3748 (not supported in PXM 4000) SagLev2 Uint16 114154 3749 (not supported in PXM 4000) SagLev4 Uint16 114155 374A (not supported in PXM 4000) SagLev8 Uint16 114156 374B (not supported in PXM 4000) SwellLev1 Uint16 114157 374C (not supported in PXM 4000) SwellLev2 Uint16 1



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14158 374D (not supported in PXM 4000) SwellLev4 Uint16 114159 374E (not supported in PXM 4000) SwellLev8 Uint16 1

19384 4BB7PQIndex

PQlatest10min Float 219386 4BB9 PQlatest24hour Float 219388 4BBB MeanPQ Float 219404 4BCB (not supported in PXM 4000) SagLevel Float 219406 4BCD (not supported in PXM 4000) SwellLevel Float 219408 4BCF DvDtCount Float 219410 4BD1 THDIavg Float 219412 4BD3 THDVavg Float 219414 4BD5 (not supported in PXM 4000) Pst Float 219428 4BE3 (not supported in PXM 4000) SagScore Float 219430 4BE5 (not supported in PXM 4000) SwellScore Float 219432 4BE7 DvDtScore Float 219434 4BE9 THDIavgScore Float 219436 4BEB THDVavgScore Float 219438 4BED (not supported in PXM 4000) PstScore Float 219440 4BEF PQResetTime Date 6

B.3. Minimum and Maximum Register Map

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19446 4BF5 Minimums Van Float 219448 4BF7 Vbn Float 219450 4BF9 Vcn Float 219452 4BFB Vlnavg Float 219454 4BFD Vng Float 219456 4BFF Vab Float 219458 4C01 Vbc Float 219460 4C03 Vca Float 219462 4C05 Vllavg Float 219464 4C07 Vab2 Float 219466 4C09 Vbc2 Float 219468 4C0B Vca2 Float 219470 4C0D VLLavg2 Float 219472 4C0F Ia Float 219474 4C11 Ib Float 219476 4C13 Ic Float 2



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19478 4C15 In Float 219480 4C17 Ig Float 219482 4C19 SystemFrequency Float 219484 4C1B PFaApparent Float 219486 4C1D PFbApparent Float 219488 4C1F PFcApparent Float 219490 4C21 PFsysApparent Float 219492 4C23 PFaDisplacement Float 219494 4C25 PFbDisplacement Float 219496 4C27 PFcDisplacement Float 219498 4C29 PFsysDisplacement Float 219500 4C2B (not supported in PXM 4000) FlickerVan Float 219502 4C2D (not supported in PXM 4000) FlickerVbn Float 219504 4C2F (not supported in PXM 4000) FlickerVcn Float 219506 4C31 (not supported in PXM 4000) FlickerVab Float 219508 4C33 (not supported in PXM 4000) FlickerVbc Float 219510 4C35 (not supported in PXM 4000) FlickerVca Float 219512 4C37 CrestFactorIa Float 219514 4C39 CrestFactorIb Float 219516 4C3B CrestFactorIc Float 219518 4C3D CrestFactorSys Float 219520 4C3F KFactorIa Float 219522 4C41 KFactorIb Float 219524 4C43 KFactorIc Float 219526 4C45 KFactorSys Float 219528 4C47 MinMaxResetTime Date 619534 4C4D MinTimeStamp Van Date 619540 4C53 Vbn Date 619546 4C59 Vcn Date 619552 4C5F Vlnavg Date 619558 4C65 Vng Date 619564 4C6B Vab Date 619570 4C71 Vbc Date 619576 4C77 Vca Date 619582 4C7D Vllavg Date 619588 4C83 Vab2 Date 6



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19594 4C89 Vbc2 Date 619600 4C8F Vca2 Date 619606 4C95 VLLavg2 Date 619612 4C9B Ia Date 619618 4CA1 Ib Date 619624 4CA7 Ic Date 619630 4CAD In Date 619636 4CB3 Ig Date 619642 4CB9 SystemFrequency Date 619648 4CBF PFaApparent Date 619654 4CC5 PFbApparent Date 619660 4CCB PFcApparent Date 619666 4CD1 PFsysApparent Date 619672 4CD7 PFaDisplacement Date 619678 4CDD PFbDisplacement Date 619684 4CE3 PFcDisplacement Date 619690 4CE9 PFsysDisplacement Date 619696 4CEF (not supported in PXM 4000) FlickerVan Date 619702 4CF5 (not supported in PXM 4000) FlickerVbn Date 619708 4CFB (not supported in PXM 4000) FlickerVcn Date 619714 4D01 (not supported in PXM 4000) FlickerVab Date 619720 4D07 (not supported in PXM 4000) FlickerVbc Date 619726 4D0D (not supported in PXM 4000) FlickerVca Date 619732 4D13 CrestFactorIa Date 619738 4D19 CrestFactorIb Date 619744 4D1F CrestFactorIc Date 619750 4D25 CrestFactorSys Date 619756 4D2B KFactorIa Date 619762 4D31 KFactorIb Date 619768 4D37 KFactorIc Date 619774 4D3D KFactorSys Date 619780 4D43 MinMaxResetTime Date 619786 4D49 Maximums Van Float 219788 4D4B Vbn Float 219790 4D4D Vcn Float 219792 4D4F Vlnavg Float 219794 4D51 Vng Float 219796 4D53 Vab Float 219798 4D55 Vbc Float 219800 4D57 Vca Float 219802 4D59 Vllavg Float 219804 4D5B Vab2 Float 2



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19806 4D5D Vbc2 Float 219808 4D5F Vca2 Float 219810 4D61 VLLavg2 Float 219812 4D63 Ia Float 219814 4D65 Ib Float 219816 4D67 Ic Float 219818 4D69 In Float 219820 4D6B Ig Float 219822 4D6D SystemFrequency Float 219824 4D6F PFaApparent Float 219826 4D71 PFbApparent Float 219828 4D73 PFcApparent Float 219830 4D75 PFsysApparent Float 219832 4D77 PFaDisplacement Float 219834 4D79 PFbDisplacement Float 219836 4D7B PFcDisplacement Float 219838 4D7D PFsysDisplacement Float 219840 4D7F (not supported in PXM 4000) FlickerVan Float 219842 4D81 (not supported in PXM 4000) FlickerVbn Float 219844 4D83 (not supported in PXM 4000) FlickerVcn Float 219846 4D85 (not supported in PXM 4000) FlickerVab Float 219848 4D87 (not supported in PXM 4000) FlickerVbc Float 219850 4D89 (not supported in PXM 4000) FlickerVca Float 219852 4D8B CrestFactorIa Float 219854 4D8D CrestFactorIb Float 219856 4D8F CrestFactorIc Float 219858 4D91 CrestFactorSys Float 219860 4D93 KFactorIa Float 219862 4D95 KFactorIb Float 219864 4D97 KFactorIc Float 219866 4D99 KFactorSys Float 219868 4D9B MinMaxResetTime Date 619874 4DA1 MaxTimeStamp Van Date 619880 4DA7 Vbn Date 619886 4DAD Vcn Date 619892 4DB3 Vlnavg Date 619898 4DB9 Vng Date 619904 4DBF Vab Date 619910 4DC5 Vbc Date 619916 4DCB Vca Date 619922 4DD1 Vllavg Date 619928 4DD7 Vab2 Date 6



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19934 4DDD Vbc2 Date 619940 4DE3 Vca2 Date 619946 4DE9 VLLavg2 Date 619952 4DEF Ia Date 619958 4DF5 Ib Date 619964 4DFB Ic Date 619970 4E01 In Date 619976 4E07 Ig Date 619982 4E0D SystemFrequency Date 619988 4E13 PFaApparent Date 619994 4E19 PFbApparent Date 620000 4E1F PFcApparent Date 620006 4E25 PFsysApparent Date 620012 4E2B PFaDisplacement Date 620018 4E31 PFbDisplacement Date 620024 4E37 PFcDisplacement Date 620030 4E3D PFsysDisplacement Date 620036 4E43 (not supported in the PXM 4000) FlickerVan Date 620042 4E49 (not supported in the PXM 4000) FlickerVbn Date 620048 4E4F (not supported in the PXM 4000) FlickerVcn Date 620054 4E55 (not supported in the PXM 4000) FlickerVab Date 620060 4E5B (not supported in the PXM 4000) FlickerVbc Date 620066 4E61 (not supported in the PXM 4000) FlickerVca Date 620072 4E67 CrestFactorIa Date 620078 4E6D CrestFactorIb Date 620084 4E73 CrestFactorIc Date 620090 4E79 CrestFactorSys Date 620096 4E7F KFactorIa Date 620102 4E85 KFactorIb Date 620108 4E8B KFactorIc Date 620114 4E91 KFactorSys Date 620120 4E97 MinMaxResetTime Date 6

B.4. I/O Register Map

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20126 4E9D Discrete Input 1 Function Uint16 120127 4E9E Discrete Input 2 Function Uint16 120128 4E9F Discrete Input 3 Function Uint16 1



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20129 4EA0 Discrete Input 4 Function Uint16 120130 4EA1 Discrete Input 5 Function Uint16 120131 4EA2 Discrete Input 6 Function Uint16 120132 4EA3 Discrete Input 7 Function Uint16 120133 4EA4 Discrete Input 8 Function Uint16 120134 4EA5 Solid State Relay 1 Function Uint16 120135 4EA6 Solid State Relay 2 Function Uint16 120136 4EA7 Form-C Relay 1 Function Uint16 120137 4EA8 Form-C Relay 2 Function Uint16 120138 4EA9 Form-C Relay 3 Function Uint16 120139 4EAA Discrete Input 1 Status Uint16 120140 4EAB Discrete Input 2 Status Uint16 120141 4EAC Discrete Input 3 Status Uint16 120142 4EAD Discrete Input 4 Status Uint16 120143 4EAE Discrete Input 5 Status Uint16 120144 4EAF Discrete Input 6 Status Uint16 120145 4EB0 Discrete Input 7 Status Uint16 120146 4EB1 Discrete Input 8 Status Uint16 120147 4EB2 Solid State Relay 1 Status Uint16 120148 4EB3 Solid State Relay 2 Status Uint16 120149 4EB4 Form-C Relay 1 Status Uint16 120150 4EB5 Form-C Relay 2 Status Uint16 120151 4EB6 Form-C Relay 3 Status Uint16 120152 4EB7 Discrete Input 1 Count Uint16 120153 4EB8 Discrete Input 2 Count Uint16 120154 4EB9 Discrete Input 3 Count Uint16 120155 4EBA Discrete Input 4 Count Uint16 120156 4EBB Discrete Input 5 Count Uint16 120157 4EBC Discrete Input 6 Count Uint16 120158 4EBD Discrete Input 7 Count Uint16 120159 4EBE Discrete Input 8 Count Uint16 120160 4EBF Solid State Relay 1 Count Uint16 120161 4EC0 Solid State Relay 2 Count Uint16 120162 4EC1 Form-C Relay 1 Count Uint16 120163 4EC2 Form-C Relay 2 Count Uint16 120164 4EC3 Form-C Relay 3 Count Uint16 1

B.5. Appendix E – Event Trigger Register Map



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18620 48BB EventTriggerPushDownList[0] EventID Uint32 218622 48BD EventTime Date 618628 48C3 Cause Uint16 118629 48C4 Param1 Float 218631 48C6 Waveform Id (0xffffffff if none) Uint32 218633 48C8 EventTriggerPushDownList[1] EventID Uint32 218635 48CA EventTime Date 618641 48D0 Cause Uint16 118642 48D1 Param1 Float 218644 48D3 Waveform Id (0xffffffff if none) Uint32 218646 48D5 EventTriggerPushDownList[2] EventID Uint32 218648 48D7 EventTime Date 618654 48DD Cause Uint16 118655 48DE Param1 Float 218657 48E0 Waveform Id (0xffffffff if none) Uint32 218659 48E2 EventTriggerPushDownList[3] EventID Uint32 218661 48E4 EventTime Date 618667 48EA Cause Uint16 118668 48EB Param1 Float 218670 48ED Waveform Id (0xffffffff if none) Uint32 218672 48EF EventTriggerPushDownList[4] EventID Uint32 218674 48F1 EventTime Date 618680 48F7 Cause Uint16 118681 48F8 Param1 Float 218683 48FA Waveform Id (0xffffffff if none) Uint32 218685 48FC EventTriggerPushDownList[5] EventID Uint32 218687 48FE EventTime Date 618693 4904 Cause Uint16 118694 4905 Param1 Float 218696 4907 Waveform Id (0xffffffff if none) Uint32 218698 4909 EventTriggerPushDownList[6] EventID Uint32 218700 490B EventTime Date 618706 4911 Cause Uint16 118707 4912 Param1 Float 218709 4914 Waveform Id (0xffffffff if none) Uint32 218711 4916 EventTriggerPushDownList[7] EventID Uint32 218713 4918 EventTime Date 618719 491E Cause Uint16 118720 491F Param1 Float 218722 4921 Waveform Id (0xffffffff if none) Uint32 218724 4923 EventTriggerPushDownList[8] EventID Uint32 2



18726 4925 EventTime Date 618732 492B Cause Uint16 118733 492C Param1 Float 218735 492E Waveform Id (0xffffffff if none) Uint32 218737 4930 EventTriggerPushDownList[9] EventID Uint32 218739 4932 EventTime Date 618745 4938 Cause Uint16 118746 4939 Param1 Float 218748 493B Waveform Id (0xffffffff if none) Uint32 218750 493D EventTriggerPushDownList[10] EventID Uint32 218752 493F EventTime Date 618758 4945 Cause Uint16 118759 4946 Param1 Float 218761 4948 Waveform Id (0xffffffff if none) Uint32 218763 494A EventTriggerPushDownList[11] EventID Uint32 218765 494C EventTime Date 618771 4952 Cause Uint16 118772 4953 Param1 Float 218774 4955 Waveform Id (0xffffffff if none) Uint32 218776 4957 EventTriggerPushDownList[12] EventID Uint32 218778 4959 EventTime Date 618784 495F Cause Uint16 118785 4960 Param1 Float 218787 4962 Waveform Id (0xffffffff if none) Uint32 218789 4964 EventTriggerPushDownList[13] EventID Uint32 218791 4966 EventTime Date 618797 496C Cause Uint16 118798 496D Param1 Float 218800 496F Waveform Id (0xffffffff if none) Uint32 218802 4971 EventTriggerPushDownList[14] EventID Uint32 218804 4973 EventTime Date 618810 4979 Cause Uint16 118811 497A Param1 Float 218813 497C Waveform Id (0xffffffff if none) Uint32 218815 497E EventTriggerPushDownList[15] EventID Uint32 218817 4980 EventTime Date 618823 4986 Cause Uint16 118824 4987 Param1 Float 218826 4989 Waveform Id (0xffffffff if none) Uint32 218828 498B EventTriggerPushDownList[16] EventID Uint32 218830 498D EventTime Date 618836 4993 Cause Uint16 118837 4994 Param1 Float 218839 4996 Waveform Id (0xffffffff if none) Uint32 218841 4998 EventTriggerPushDownList[17] EventID Uint32 2



18843 499A EventTime Date 618849 49A0 Cause Uint16 118850 49A1 Param1 Float 218852 49A3 Waveform Id (0xffffffff if none) Uint32 218854 49A5 EventTriggerPushDownList[18] EventID Uint32 218856 49A7 EventTime Date 618862 49AD Cause Uint16 118863 49AE Param1 Float 218865 49B0 Waveform Id (0xffffffff if none) Uint32 218867 49B2 EventTriggerPushDownList[19] EventID Uint32 218869 49B4 EventTime Date 618875 49BA Cause Uint16 118876 49BB Param1 Float 218878 49BD Waveform Id (0xffffffff if none) Uint32 2

B.6. Event Log Register Map

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29000 7147 EventLogPushDownList[0] EventID Uint32 229002 7149 EventTime Date 629008 714F Number of Bytes (1-150) Uint16 129009 7150 ASCII string (1-150 characters) Char 7529084 719B EventLogPushDownList[1] EventID Uint32 229086 719D EventTime Date 629092 71A3 Number of Bytes (1-150) Uint16 129093 71A4 ASCII string (1-150 characters) Char 7529168 71EF EventLogPushDownList[2] EventID Uint32 229170 71F1 EventTime Date 629176 71F7 Number of Bytes (1-150) Uint16 129177 71F8 ASCII string (1-150 characters) Char 7529252 7243 EventLogPushDownList[3] EventID Uint32 229254 7245 EventTime Date 629260 724B Number of Bytes (1-150) Uint16 129261 724C ASCII string (1-150 characters) Char 7529336 7297 EventLogPushDownList[4] EventID Uint32 229338 7299 EventTime Date 629344 729F Number of Bytes (1-150) Uint16 129345 72A0 ASCII string (1-150 characters) Char 7529420 72EB EventLogPushDownList[5] EventID Uint32 229422 72ED EventTime Date 629428 72F3 Number of Bytes (1-150) Uint16 1



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29429 72F4 ASCII string (1-150 characters) Char 7529504 733F EventLogPushDownList[6] EventID Uint32 229506 7341 EventTime Date 629512 7347 Number of Bytes (1-150) Uint16 129513 7348 ASCII string (1-150 characters) Char 7529588 7393 EventLogPushDownList[7] EventID Uint32 229590 7395 EventTime Date 629596 739B Number of Bytes (1-150) Uint16 129597 739C ASCII string (1-150 characters) Char 7529672 73E7 EventLogPushDownList[8] EventID Uint32 229674 73E9 EventTime Date 629680 73EF Number of Bytes (1-150) Uint16 129681 73F0 ASCII string (1-150 characters) Char 7529756 743B EventLogPushDownList[9] EventID Uint32 229758 743D EventTime Date 629764 7443 Number of Bytes (1-150) Uint16 129765 7444 ASCII string (1-150 characters) Char 7529840 748F EventLogPushDownList[10] EventID Uint32 229842 7491 EventTime Date 629848 7497 Number of Bytes (1-150) Uint16 129849 7498 ASCII string (1-150 characters) Char 7529924 74E3 EventLogPushDownList[11] EventID Uint32 229926 74E5 EventTime Date 629932 74EB Number of Bytes (1-150) Uint16 129933 74EC ASCII string (1-150 characters) Char 7530008 7537 EventLogPushDownList[12] EventID Uint32 230010 7539 EventTime Date 630016 753F Number of Bytes (1-150) Uint16 130017 7540 ASCII string (1-150 characters) Char 7530092 758B EventLogPushDownList[13] EventID Uint32 230094 758D EventTime Date 630100 7593 Number of Bytes (1-150) Uint16 130101 7594 ASCII string (1-150 characters) Char 7530176 75DF EventLogPushDownList[14] EventID Uint32 230178 75E1 EventTime Date 630184 75E7 Number of Bytes (1-150) Uint16 130185 75E8 ASCII string (1-150 characters) Char 7530260 7633 EventLogPushDownList[15] EventID Uint32 230262 7635 EventTime Date 630268 763B Number of Bytes (1-150) Uint16 130269 763C ASCII string (1-150 characters) Char 75



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30344 7687 EventLogPushDownList[16] EventID Uint32 230346 7689 EventTime Date 630352 768F Number of Bytes (1-150) Uint16 130353 7690 ASCII string (1-150 characters) Char 7530428 76DB EventLogPushDownList[17] EventID Uint32 230430 76DD EventTime Date 630436 76E3 Number of Bytes (1-150) Uint16 130437 76E4 ASCII string (1-150 characters) Char 7530512 772F EventLogPushDownList[18] EventID Uint32 230514 7731 EventTime Date 630520 7737 Number of Bytes (1-150) Uint16 130521 7738 ASCII string (1-150 characters) Char 7530596 7783 EventLogPushDownList[19] EventID Uint32 230598 7785 EventTime Date 630604 778B Number of Bytes (1-150) Uint16 130605 778C ASCII string (1-150 characters) Char 7530680 77D7

B.7. Trend and Profile Query Register Map

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26050 65C1 Query for Trend Data Trend

Channel (read/write) Write modbus reg value of measurement to fetch [deci-mal register number minus 1] (see table) Uint16 1

26051 65C2

Interval (read/write) [seconds: e.g. 5minutes = 300seconds and 15 minutes = 900seconds, 60 minute = 3600seconds 10080] Uint16 1

26052 65C3Page (read/write) [page zero is the most recent data] Uint16 1

26053 65C4 TimestampOfLatestValues (read only) Date 626059 65CA Pages (read only) Uint16 126060 65CB MinData [192 samples] (read only) Float 38426444 674B MaxData [192 samples] (read only) Float 384



26828 68CB AvgData [192 samples] (read only) Float 384

27212 6A4B Query for Demand Profiles

Demand Channel (read/write) Write modbus reg value of measurement to fetch [decimal register number minus 1] (see table) Uint16 1

27213 6A4C

Interval (read/write) [minutes: vari-able interval [default=15min], 1day=1440minutes, Uint16 1

27214 6A4D TimestampOfLatestValues (read only) Date 6

27220 6A53DemandData [up to 576 values] (read only) Float 1152

28372 6ED3

B.8. Latest Min/Max/Avg Register Map

The following registers are organized in groups. Each row represents 3 values, the latest minimum, the latest maximum, and the latest average.

Min

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age

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ts31000 7917

Time of last trend record 5 min Timestamp

31006 791d 31008 791f 31010 7921 PosSeqV 5 min float V31012 7923 31014 7925 31016 7927 NegSeqV 5 min float V31018 7929 31020 792b 31022 792d ZeroSeqV 5 min float V31024 792f 31026 7931 31028 7933 PosSeqI 5 min float A31030 7935 31032 7937 31034 7939 NegSeqI 5 min float A31036 793b 31038 793d 31040 793f ZeroSeqI 5 min float A31042 7941 31044 7943 31046 7945 PosSeqVxmr 5 min float V31048 7947 31050 7949 31052 794b NegSeqVxmr 5 min float V31054 794d 31056 794f 31058 7951 ZeroSeqVxmr 5 min float V31060 7953 31062 7955 31064 7957 Van200 5 min float V31066 7959 31068 795b 31070 795d Vbn200 5 min float V31072 795f 31074 7961 31076 7963 Vcn200 5 min float V31078 7965 31080 7967 31082 7969 Vlnavg200 5 min float V31084 796b 31086 796d 31088 796f Vng200 5 min float V31090 7971 31092 7973 31094 7975 Vab200 5 min float V31096 7977 31098 7979 31100 797b Vbc200 5 min float V31102 797d 31104 797f 31106 7981 Vca200 5 min float V31108 7983 31110 7985 31112 7987 Vllavg200 5 min float V31114 7989 31116 798b 31118 798d Ia200 5 min float A31120 798f 31122 7991 31124 7993 Ib200 5 min float A31126 7995 31128 7997 31130 7999 Ic200 5 min float A



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31132 799b 31134 799d 31136 799f Iavg200 5 min float A31138 79a1 31140 79a3 31142 79a5 In200 5 min float A31144 79a7 31146 79a9 31148 79ab Ig200 5 min float A31150 79ad 31152 79af 31154 79b1 Vabxmr200 5 min float V31156 79b3 31158 79b5 31160 79b7 Vbcxmr200 5 min float V31162 79b9 31164 79bb 31166 79bd Vcaxmr200 5 min float V31168 79bf 31170 79c1 31172 79c3 Vllavgxmr200 5 min float V31174 79c5 31176 79c7 31178 79c9 Fsys 5 min float Hz31180 79cb 31182 79cd 31184 79cf APFa 5 min float31186 79d1 31188 79d3 31190 79d5 APFb 5 min float31192 79d7 31194 79d9 31196 79db APFc 5 min float31198 79dd 31200 79df 31202 79e1 APFsys 5 min float31204 79e3 31206 79e5 31208 79e7 DPFa 5 min float31210 79e9 31212 79eb 31214 79ed DPFb 5 min float31216 79ef 31218 79f1 31220 79f3 DPFc 5 min float31222 79f5 31224 79f7 31226 79f9 DPFsys 5 min float31228 79fb 31230 79fd 31232 79ff CFa 5 min float31234 7a01 31236 7a03 31238 7a05 CFb 5 min float31240 7a07 31242 7a09 31244 7a0b CFc 5 min float31246 7a0d 31248 7a0f 31250 7a11 CFsys 5 min float31252 7a13 31254 7a15 31256 7a17 IFa 5 min float31258 7a19 31260 7a1b 31262 7a1d IFb 5 min float31264 7a1f 31266 7a21 31268 7a23 IFc 5 min float31270 7a25 31272 7a27 31274 7a29 IFsys 5 min float31276 7a2b 31278 7a2d 31280 7a2f FlickerPerceptVan 5 min float31282 7a31 31284 7a33 31286 7a35 FlickerPerceptVbn 5 min float31288 7a37 31290 7a39 31292 7a3b FlickerPerceptVcn 5 min float31294 7a3d 31296 7a3f 31298 7a41 FlickerPerceptVab 5 min float31300 7a43 31302 7a45 31304 7a47 FlickerPerceptVbc 5 min float31306 7a49 31308 7a4b 31310 7a4d FlickerPerceptVca 5 min float31312 7a4f 31314 7a51 31316 7a53 FlickerPerceptSys 5 min float 31318 7a55 31320 7a57 31322 7a59 Pa 5 min float W31324 7a5b 31326 7a5d 31328 7a5f Pb 5 min float W31330 7a61 31332 7a63 31334 7a65 Pc 5 min float W31336 7a67 31338 7a69 31340 7a6b Ptotal 5 min float W31342 7a6d 31344 7a6f 31346 7a71 Qa 5 min float var31348 7a73 31350 7a75 31352 7a77 Qb 5 min float var31354 7a79 31356 7a7b 31358 7a7d Qc 5 min float var31360 7a7f 31362 7a81 31364 7a83 Qtotal 5 min float var



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31366 7a85 31368 7a87 31370 7a89 Sa 5 min float VA31372 7a8b 31374 7a8d 31376 7a8f Sb 5 min float VA31378 7a91 31380 7a93 31382 7a95 Sc 5 min float VA31384 7a97 31386 7a99 31388 7a9b Stotal 5 min float VA31390 7a9d 31392 7a9f 31394 7aa1 KFa 5 min float31396 7aa3 31398 7aa5 31400 7aa7 KFb 5 min float31402 7aa9 31404 7aab 31406 7aad KFc 5 min float31408 7aaf 31410 7ab1 31412 7ab3 KFsys 5 min float31414 7ab5 31416 7ab7 31418 7ab9 EvenHarmonicVan 5 min float V31420 7abb 31422 7abd 31424 7abf OddHarmonicVan 5 min float V31426 7ac1 31428 7ac3 31430 7ac5 InterHarmonicVan 5 min float V31432 7ac7 31434 7ac9 31436 7acb TotalHarmonicVan 5 min float V31438 7acd 31440 7acf 31442 7ad1 EvenHarmonicVbn 5 min float V31444 7ad3 31446 7ad5 31448 7ad7 OddHarmonicVbn 5 min float V31450 7ad9 31452 7adb 31454 7add InterHarmonicVbn 5 min float V31456 7adf 31458 7ae1 31460 7ae3 TotalHarmonicVbn 5 min float V31462 7ae5 31464 7ae7 31466 7ae9 EvenHarmonicVcn 5 min float V31468 7aeb 31470 7aed 31472 7aef OddHarmonicVcn 5 min float V31474 7af1 31476 7af3 31478 7af5 InterHarmonicVcn 5 min float V31480 7af7 31482 7af9 31484 7afb TotalHarmonicVcn 5 min float V31486 7afd 31488 7aff 31490 7b01 EvenHarmonicVab 5 min float V31492 7b03 31494 7b05 31496 7b07 OddHarmonicVab 5 min float V31498 7b09 31500 7b0b 31502 7b0d InterHarmonicVab 5 min float V31504 7b0f 31506 7b11 31508 7b13 TotalHarmonicVab 5 min float V31510 7b15 31512 7b17 31514 7b19 EvenHarmonicVbc 5 min float V31516 7b1b 31518 7b1d 31520 7b1f OddHarmonicVbc 5 min float V31522 7b21 31524 7b23 31526 7b25 InterHarmonicVbc 5 min float V31528 7b27 31530 7b29 31532 7b2b TotalHarmonicVbc 5 min float V31534 7b2d 31536 7b2f 31538 7b31 EvenHarmonicVca 5 min float V31540 7b33 31542 7b35 31544 7b37 OddHarmonicVca 5 min float V31546 7b39 31548 7b3b 31550 7b3d InterHarmonicVca 5 min float V31552 7b3f 31554 7b41 31556 7b43 TotalHarmonicVca 5 min float V31558 7b45 31560 7b47 31562 7b49 EvenHarmonicVabxmr 5 min float V31564 7b4b 31566 7b4d 31568 7b4f OddHarmonicVabxmr 5 min float V31570 7b51 31572 7b53 31574 7b55 InterHarmonicVabxmr 5 min float V31576 7b57 31578 7b59 31580 7b5b TotalHarmonicVabxmr 5 min float V31582 7b5d 31584 7b5f 31586 7b61 EvenHarmonicVbcxmr 5 min float V31588 7b63 31590 7b65 31592 7b67 OddHarmonicVbcxmr 5 min float V



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31594 7b69 31596 7b6b 31598 7b6d InterHarmonicVbcxmr 5 min float V31600 7b6f 31602 7b71 31604 7b73 TotalHarmonicVbcxmr 5 min float V31606 7b75 31608 7b77 31610 7b79 EvenHarmonicVcaxmr 5 min float V31612 7b7b 31614 7b7d 31616 7b7f OddHarmonicVcaxmr 5 min float V31618 7b81 31620 7b83 31622 7b85 InterHarmonicVcaxmr 5 min float V31624 7b87 31626 7b89 31628 7b8b TotalHarmonicVcaxmr 5 min float V31630 7b8d 31632 7b8f 31634 7b91 EvenHarmonicIa 5 min float A31636 7b93 31638 7b95 31640 7b97 OddHarmonicIa 5 min float A31642 7b99 31644 7b9b 31646 7b9d InterHarmonicIa 5 min float A31648 7b9f 31650 7ba1 31652 7ba3 TotalHarmonicIa 5 min float A31654 7ba5 31656 7ba7 31658 7ba9 EvenHarmonicIb 5 min float A31660 7bab 31662 7bad 31664 7baf OddHarmonicIb 5 min float A31666 7bb1 31668 7bb3 31670 7bb5 InterHarmonicIb 5 min float A31672 7bb7 31674 7bb9 31676 7bbb TotalHarmonicIb 5 min float A31678 7bbd 31680 7bbf 31682 7bc1 EvenHarmonicIc 5 min float A31684 7bc3 31686 7bc5 31688 7bc7 OddHarmonicIc 5 min float A31690 7bc9 31692 7bcb 31694 7bcd InterHarmonicIc 5 min float A31696 7bcf 31698 7bd1 31700 7bd3 TotalHarmonicIc 5 min float A31702 7bd5 31704 7bd7 31706 7bd9 EvenHarmonicIn 5 min float A31708 7bdb 31710 7bdd 31712 7bdf OddHarmonicIn 5 min float A31714 7be1 31716 7be3 31718 7be5 InterHarmonicIn 5 min float A31720 7be7 31722 7be9 31724 7beb TotalHarmonicIn 5 min float A31726 7bed 31728 7bef 31730 7bf1 FundamentalVan 5 min float 31732 7bf3 31734 7bf5 31736 7bf7 FundamentalVbn 5 min float 31738 7bf9 31740 7bfb 31742 7bfd FundamentalVcn 5 min float 31744 7bff 31746 7c01 31748 7c03 FundamentalVab 5 min float 31750 7c05 31752 7c07 31754 7c09 FundamentalVbc 5 min float 31756 7c0b 31758 7c0d 31760 7c0f FundamentalVca 5 min float 31762 7c11 31764 7c13 31766 7c15 FundamentalVabxmr 5 min float 31768 7c17 31770 7c19 31772 7c1b FundamentalVbcxmr 5 min float 31774 7c1d 31776 7c1f 31778 7c21 FundamentalVcaxmr 5 min float 31780 7c23 31782 7c25 31784 7c27 FundamentalIa 5 min float 31786 7c29 31788 7c2b 31790 7c2d FundamentalIb 5 min float 31792 7c2f 31794 7c31 31796 7c33 FundamentalIc 5 min float 31798 7c35 31800 7c37 31802 7c39 FundamentalIn 5 min float 31804 7c3b 31806 7c3d 31808 7c3f PstVan 5 min float31810 7c41 31812 7c43 31814 7c45 PstVbn 5 min float31816 7c47 31818 7c49 31820 7c4b PstVcn 5 min float31822 7c4d 31824 7c4f 31826 7c51 PstVab 5 min float



Min

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)

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Reg

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Max

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Aver

age

Reg

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Aver

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Des

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Type

Uni

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31828 7c53 31830 7c55 31832 7c57 PstVbc 5 min float31834 7c59 31836 7c5b 31838 7c5d PstVca 5 min float31840 7c5f 31842 7c61 31844 7c63 PstSys 5 min float 31846 7c65 31848 7c67 31850 7c69 PltVan 5 min float31852 7c6b 31854 7c6d 31856 7c6f PltVbn 5 min float31858 7c71 31860 7c73 31862 7c75 PltVcn 5 min float31864 7c77 31866 7c79 31868 7c7b PltVab 5 min float31870 7c7d 31872 7c7f 31874 7c81 PltVbc 5 min float31876 7c83 31878 7c85 31880 7c87 PltVca 5 min float31882 7c89 31884 7c8b 31886 7c8d PltVSys 5 min float31888 7c8f 31890 7c91 31892 7c93 EvenHarmVanPct 5 min float ratio31894 7c95 31896 7c97 31898 7c99 OddHarmVanPct 5 min float ratio31900 7c9b 31902 7c9d 31904 7c9f InterHarmVanPct 5 min float ratio31906 7ca1 31908 7ca3 31910 7ca5 TotalHarmVanPct 5 min float ratio31912 7ca7 31914 7ca9 31916 7cab EvenHarmVbnPct 5 min float ratio31918 7cad 31920 7caf 31922 7cb1 OddHarmVbnPct 5 min float ratio31924 7cb3 31926 7cb5 31928 7cb7 InterHarmVbnPct 5 min float ratio31930 7cb9 31932 7cbb 31934 7cbd TotalHarmVbnPct 5 min float ratio31936 7cbf 31938 7cc1 31940 7cc3 EvenHarmVcnPct 5 min float ratio31942 7cc5 31944 7cc7 31946 7cc9 OddHarmVcnPct 5 min float ratio31948 7ccb 31950 7ccd 31952 7ccf InterHarmVcnPct 5 min float ratio31954 7cd1 31956 7cd3 31958 7cd5 TotalHarmVcnPct 5 min float ratio31960 7cd7 31962 7cd9 31964 7cdb EvenHarmVabPct 5 min float ratio31966 7cdd 31968 7cdf 31970 7ce1 OddHarmVabPct 5 min float ratio31972 7ce3 31974 7ce5 31976 7ce7 InterHarmVabPct 5 min float ratio31978 7ce9 31980 7ceb 31982 7ced TotalHarmVabPct 5 min float ratio31984 7cef 31986 7cf1 31988 7cf3 EvenHarmVbcPct 5 min float ratio31990 7cf5 31992 7cf7 31994 7cf9 OddHarmVbcPct 5 min float ratio31996 7cfb 31998 7cfd 32000 7cff InterHarmVbcPct 5 min float ratio32002 7d01 32004 7d03 32006 7d05 TotalHarmVbcPct 5 min float ratio32008 7d07 32010 7d09 32012 7d0b EvenHarmVcaPct 5 min float ratio32014 7d0d 32016 7d0f 32018 7d11 OddHarmVcaPct 5 min float ratio32020 7d13 32022 7d15 32024 7d17 InterHarmVcaPct 5 min float ratio32026 7d19 32028 7d1b 32030 7d1d TotalHarmVcaPct 5 min float ratio32032 7d1f 32034 7d21 32036 7d23 EvenHarmVabxmrPct 5 min float ratio32038 7d25 32040 7d27 32042 7d29 OddHarmVabxmrPct 5 min float ratio32044 7d2b 32046 7d2d 32048 7d2f InterHarmVabxmrPct 5 min float ratio32050 7d31 32052 7d33 32054 7d35 TotalHarmVabxmrPct 5 min float ratio32056 7d37 32058 7d39 32060 7d3b EvenHarmVbcxmrPct 5 min float ratio



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32062 7d3d 32064 7d3f 32066 7d41 OddHarmVbcxmrPct 5 min float ratio32068 7d43 32070 7d45 32072 7d47 InterHarmVbcxmrPct 5 min float ratio32074 7d49 32076 7d4b 32078 7d4d TotalHarmVbcxmrPct 5 min float ratio32080 7d4f 32082 7d51 32084 7d53 EvenHarmVcaxmrPct 5 min float ratio32086 7d55 32088 7d57 32090 7d59 OddHarmVcaxmrPct 5 min float ratio32092 7d5b 32094 7d5d 32096 7d5f InterHarmVcaxmrPct 5 min float ratio32098 7d61 32100 7d63 32102 7d65 TotalHarmVcaxmrPct 5 min float ratio32104 7d67 32106 7d69 32108 7d6b EvenHarmIaPct 5 min float ratio32110 7d6d 32112 7d6f 32114 7d71 OddHarmIaPct 5 min float ratio32116 7d73 32118 7d75 32120 7d77 InterHarmIaPct 5 min float ratio32122 7d79 32124 7d7b 32126 7d7d TotalHarmIaPct 5 min float ratio32128 7d7f 32130 7d81 32132 7d83 EvenHarmIbPct 5 min float ratio32134 7d85 32136 7d87 32138 7d89 OddHarmIbPct 5 min float ratio32140 7d8b 32142 7d8d 32144 7d8f InterHarmIbPct 5 min float ratio32146 7d91 32148 7d93 32150 7d95 TotalHarmIbPct 5 min float ratio32152 7d97 32154 7d99 32156 7d9b EvenHarmIcPct 5 min float ratio32158 7d9d 32160 7d9f 32162 7da1 OddHarmIcPct 5 min float ratio32164 7da3 32166 7da5 32168 7da7 InterHarmIcPct 5 min float ratio32170 7da9 32172 7dab 32174 7dad TotalHarmIcPct 5 min float ratio32176 7daf 32178 7db1 32180 7db3 EvenHarmInPct 5 min float ratio32182 7db5 32184 7db7 32186 7db9 OddHarmInPct 5 min float ratio32188 7dbb 32190 7dbd 32192 7dbf InterHarmInPct 5 min float ratio32194 7dc1 32196 7dc3 32198 7dc5 TotalHarmInPct 5 min float ratio33000 88b7 Time of last Trend 15 min Timestamp33006 80ed 33008 80ef 33010 80f1 PosSeqV 15 min float V33012 80f3 33014 80f5 33016 80f7 NegSeqV 15 min float V33018 80f9 33020 80fb 33022 80fd ZeroSeqV 15 min float V33024 80ff 33026 8101 33028 8103 PosSeqI 15 min float A33030 8105 33032 8107 33034 8109 NegSeqI 15 min float A33036 810b 33038 810d 33040 810f ZeroSeqI 15 min float A33042 8111 33044 8113 33046 8115 PosSeqVxmr 15 min float V33048 8117 33050 8119 33052 811b NegSeqVxmr 15 min float V33054 811d 33056 811f 33058 8121 ZeroSeqVxmr 15 min float V33060 8123 33062 8125 33064 8127 Van200 15 min float V33066 8129 33068 812b 33070 812d Vbn200 15 min float V33072 812f 33074 8131 33076 8133 Vcn200 15 min float V33078 8135 33080 8137 33082 8139 Vlnavg200 15 min float V33084 813b 33086 813d 33088 813f Vng200 15 min float V33090 8141 33092 8143 33094 8145 Vab200 15 min float V



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33096 8147 33098 8149 33100 814b Vbc200 15 min float V33102 814d 33104 814f 33106 8151 Vca200 15 min float V33108 8153 33110 8155 33112 8157 Vllavg200 15 min float V33114 8159 33116 815b 33118 815d Ia200 15 min float A33120 815f 33122 8161 33124 8163 Ib200 15 min float A33126 8165 33128 8167 33130 8169 Ic200 15 min float A33132 816b 33134 816d 33136 816f Iavg200 15 min float A33138 8171 33140 8173 33142 8175 In200 15 min float A33144 8177 33146 8179 33148 817b Ig200 15 min float A33150 817d 33152 817f 33154 8181 Vabxmr200 15 min float V33156 8183 33158 8185 33160 8187 Vbcxmr200 15 min float V33162 8189 33164 818b 33166 818d Vcaxmr200 15 min float V33168 818f 33170 8191 33172 8193 Vllavgxmr200 15 min float V33174 8195 33176 8197 33178 8199 Fsys 15 min float Hz33180 819b 33182 819d 33184 819f APFa 15 min float33186 81a1 33188 81a3 33190 81a5 APFb 15 min float33192 81a7 33194 81a9 33196 81ab APFc 15 min float33198 81ad 33200 81af 33202 81b1 APFsys 15 min float33204 81b3 33206 81b5 33208 81b7 DPFa 15 min float33210 81b9 33212 81bb 33214 81bd DPFb 15 min float33216 81bf 33218 81c1 33220 81c3 DPFc 15 min float33222 81c5 33224 81c7 33226 81c9 DPFsys 15 min float33228 81cb 33230 81cd 33232 81cf CFa 15 min float33234 81d1 33236 81d3 33238 81d5 CFb 15 min float33240 81d7 33242 81d9 33244 81db CFc 15 min float33246 81dd 33248 81df 33250 81e1 CFsys 15 min float33252 81e3 33254 81e5 33256 81e7 IFa 15 min float33258 81e9 33260 81eb 33262 81ed IFb 15 min float33264 81ef 33266 81f1 33268 81f3 IFc 15 min float33270 81f5 33272 81f7 33274 81f9 IFsys 15 min float33276 81fb 33278 81fd 33280 81ff FlickerPerceptVan 15 min float33282 8201 33284 8203 33286 8205 FlickerPerceptVbn 15 min float33288 8207 33290 8209 33292 820b FlickerPerceptVcn 15 min float33294 820d 33296 820f 33298 8211 FlickerPerceptVab 15 min float33300 8213 33302 8215 33304 8217 FlickerPerceptVbc 15 min float33306 8219 33308 821b 33310 821d FlickerPerceptVca 15 min float33312 821f 33314 8221 33316 8223 FlickerPerceptSys 15 min float 33318 8225 33320 8227 33322 8229 Pa 15 min float W



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33324 822b 33326 822d 33328 822f Pb 15 min float W33330 8231 33332 8233 33334 8235 Pc 15 min float W33336 8237 33338 8239 33340 823b Ptotal 15 min float W33342 823d 33344 823f 33346 8241 Qa 15 min float var33348 8243 33350 8245 33352 8247 Qb 15 min float var33354 8249 33356 824b 33358 824d Qc 15 min float var33360 824f 33362 8251 33364 8253 Qtotal 15 min float var33366 8255 33368 8257 33370 8259 Sa 15 min float VA33372 825b 33374 825d 33376 825f Sb 15 min float VA33378 8261 33380 8263 33382 8265 Sc 15 min float VA33384 8267 33386 8269 33388 826b Stotal 15 min float VA33390 826d 33392 826f 33394 8271 KFa 15 min float33396 8273 33398 8275 33400 8277 KFb 15 min float33402 8279 33404 827b 33406 827d KFc 15 min float33408 827f 33410 8281 33412 8283 KFsys 15 min float33414 8285 33416 8287 33418 8289 EvenHarmonicVan 15 min float V33420 828b 33422 828d 33424 828f OddHarmonicVan 15 min float V33426 8291 33428 8293 33430 8295 InterHarmonicVan 15 min float V33432 8297 33434 8299 33436 829b TotalHarmonicVan 15 min float V33438 829d 33440 829f 33442 82a1 EvenHarmonicVbn 15 min float V33444 82a3 33446 82a5 33448 82a7 OddHarmonicVbn 15 min float V33450 82a9 33452 82ab 33454 82ad InterHarmonicVbn 15 min float V33456 82af 33458 82b1 33460 82b3 TotalHarmonicVbn 15 min float V33462 82b5 33464 82b7 33466 82b9 EvenHarmonicVcn 15 min float V33468 82bb 33470 82bd 33472 82bf OddHarmonicVcn 15 min float V33474 82c1 33476 82c3 33478 82c5 InterHarmonicVcn 15 min float V33480 82c7 33482 82c9 33484 82cb TotalHarmonicVcn 15 min float V33486 82cd 33488 82cf 33490 82d1 EvenHarmonicVab 15 min float V33492 82d3 33494 82d5 33496 82d7 OddHarmonicVab 15 min float V33498 82d9 33500 82db 33502 82dd InterHarmonicVab 15 min float V33504 82df 33506 82e1 33508 82e3 TotalHarmonicVab 15 min float V33510 82e5 33512 82e7 33514 82e9 EvenHarmonicVbc 15 min float V33516 82eb 33518 82ed 33520 82ef OddHarmonicVbc 15 min float V33522 82f1 33524 82f3 33526 82f5 InterHarmonicVbc 15 min float V33528 82f7 33530 82f9 33532 82fb TotalHarmonicVbc 15 min float V33534 82fd 33536 82ff 33538 8301 EvenHarmonicVca 15 min float V33540 8303 33542 8305 33544 8307 OddHarmonicVca 15 min float V33546 8309 33548 830b 33550 830d InterHarmonicVca 15 min float V33552 830f 33554 8311 33556 8313 TotalHarmonicVca 15 min float V



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33558 8315 33560 8317 33562 8319 EvenHarmonicVabxmr 15 min float V33564 831b 33566 831d 33568 831f OddHarmonicVabxmr 15 min float V33570 8321 33572 8323 33574 8325 InterHarmonicVabxmr 15 min float V33576 8327 33578 8329 33580 832b TotalHarmonicVabxmr 15 min float V33582 832d 33584 832f 33586 8331 EvenHarmonicVbcxmr 15 min float V33588 8333 33590 8335 33592 8337 OddHarmonicVbcxmr 15 min float V33594 8339 33596 833b 33598 833d InterHarmonicVbcxmr 15 min float V33600 833f 33602 8341 33604 8343 TotalHarmonicVbcxmr 15 min float V33606 8345 33608 8347 33610 8349 EvenHarmonicVcaxmr 15 min float V33612 834b 33614 834d 33616 834f OddHarmonicVcaxmr 15 min float V33618 8351 33620 8353 33622 8355 InterHarmonicVcaxmr 15 min float V33624 8357 33626 8359 33628 835b TotalHarmonicVcaxmr 15 min float V33630 835d 33632 835f 33634 8361 EvenHarmonicIa 15 min float A33636 8363 33638 8365 33640 8367 OddHarmonicIa 15 min float A33642 8369 33644 836b 33646 836d InterHarmonicIa 15 min float A33648 836f 33650 8371 33652 8373 TotalHarmonicIa 15 min float A33654 8375 33656 8377 33658 8379 EvenHarmonicIb 15 min float A33660 837b 33662 837d 33664 837f OddHarmonicIb 15 min float A33666 8381 33668 8383 33670 8385 InterHarmonicIb 15 min float A33672 8387 33674 8389 33676 838b TotalHarmonicIb 15 min float A33678 838d 33680 838f 33682 8391 EvenHarmonicIc 15 min float A33684 8393 33686 8395 33688 8397 OddHarmonicIc 15 min float A33690 8399 33692 839b 33694 839d InterHarmonicIc 15 min float A33696 839f 33698 83a1 33700 83a3 TotalHarmonicIc 15 min float A33702 83a5 33704 83a7 33706 83a9 EvenHarmonicIn 15 min float A33708 83ab 33710 83ad 33712 83af OddHarmonicIn 15 min float A33714 83b1 33716 83b3 33718 83b5 InterHarmonicIn 15 min float A33720 83b7 33722 83b9 33724 83bb TotalHarmonicIn 15 min float A33726 83bd 33728 83bf 33730 83c1 FundamentalVan 15 min float 33732 83c3 33734 83c5 33736 83c7 FundamentalVbn 15 min float 33738 83c9 33740 83cb 33742 83cd FundamentalVcn 15 min float 33744 83cf 33746 83d1 33748 83d3 FundamentalVab 15 min float 33750 83d5 33752 83d7 33754 83d9 FundamentalVbc 15 min float 33756 83db 33758 83dd 33760 83df FundamentalVca 15 min float 33762 83e1 33764 83e3 33766 83e5 FundamentalVabxmr 15 min float 33768 83e7 33770 83e9 33772 83eb FundamentalVbcxmr 15 min float 33774 83ed 33776 83ef 33778 83f1 FundamentalVcaxmr 15 min float 33780 83f3 33782 83f5 33784 83f7 FundamentalIa 15 min float



in R

eg (d

ec)

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33786 83f9 33788 83fb 33790 83fd FundamentalIb 15 min float 33792 83ff 33794 8401 33796 8403 FundamentalIc 15 min float 33798 8405 33800 8407 33802 8409 FundamentalIn 15 min float 33804 840b 33806 840d 33808 840f PstVan 15 min float33810 8411 33812 8413 33814 8415 PstVbn 15 min float33816 8417 33818 8419 33820 841b PstVcn 15 min float33822 841d 33824 841f 33826 8421 PstVab 15 min float33828 8423 33830 8425 33832 8427 PstVbc 15 min float33834 8429 33836 842b 33838 842d PstVca 15 min float33840 842f 33842 8431 33844 8433 PstSys 15 min float 33846 8435 33848 8437 33850 8439 PltVan 15 min float33852 843b 33854 843d 33856 843f PltVbn 15 min float33858 8441 33860 8443 33862 8445 PltVcn 15 min float33864 8447 33866 8449 33868 844b PltVab 15 min float33870 844d 33872 844f 33874 8451 PltVbc 15 min float33876 8453 33878 8455 33880 8457 PltVca 15 min float33882 8459 33884 845b 33886 845d PltVSys 15 min float33888 845f 33890 8461 33892 8463 EvenHarmVanPct 15 min float ratio33894 8465 33896 8467 33898 8469 OddHarmVanPct 15 min float ratio33900 846b 33902 846d 33904 846f InterHarmVanPct 15 min float ratio33906 8471 33908 8473 33910 8475 TotalHarmVanPct 15 min float ratio33912 8477 33914 8479 33916 847b EvenHarmVbnPct 15 min float ratio33918 847d 33920 847f 33922 8481 OddHarmVbnPct 15 min float ratio33924 8483 33926 8485 33928 8487 InterHarmVbnPct 15 min float ratio33930 8489 33932 848b 33934 848d TotalHarmVbnPct 15 min float ratio33936 848f 33938 8491 33940 8493 EvenHarmVcnPct 15 min float ratio33942 8495 33944 8497 33946 8499 OddHarmVcnPct 15 min float ratio33948 849b 33950 849d 33952 849f InterHarmVcnPct 15 min float ratio33954 84a1 33956 84a3 33958 84a5 TotalHarmVcnPct 15 min float ratio33960 84a7 33962 84a9 33964 84ab EvenHarmVabPct 15 min float ratio33966 84ad 33968 84af 33970 84b1 OddHarmVabPct 15 min float ratio33972 84b3 33974 84b5 33976 84b7 InterHarmVabPct 15 min float ratio33978 84b9 33980 84bb 33982 84bd TotalHarmVabPct 15 min float ratio33984 84bf 33986 84c1 33988 84c3 EvenHarmVbcPct 15 min float ratio33990 84c5 33992 84c7 33994 84c9 OddHarmVbcPct 15 min float ratio33996 84cb 33998 84cd 34000 84cf InterHarmVbcPct 15 min float ratio34002 84d1 34004 84d3 34006 84d5 TotalHarmVbcPct 15 min float ratio34008 84d7 34010 84d9 34012 84db EvenHarmVcaPct 15 min float ratio34014 84dd 34016 84df 34018 84e1 OddHarmVcaPct 15 min float ratio



Min

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Aver

age

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)

Aver

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(hex

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Type

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34020 84e3 34022 84e5 34024 84e7 InterHarmVcaPct 15 min float ratio34026 84e9 34028 84eb 34030 84ed TotalHarmVcaPct 15 min float ratio34032 84ef 34034 84f1 34036 84f3 EvenHarmVabxmrPct 15 min float ratio34038 84f5 34040 84f7 34042 84f9 OddHarmVabxmrPct 15 min float ratio34044 84fb 34046 84fd 34048 84ff InterHarmVabxmrPct 15 min float ratio34050 8501 34052 8503 34054 8505 TotalHarmVabxmrPct 15 min float ratio34056 8507 34058 8509 34060 850b EvenHarmVbcxmrPct 15 min float ratio34062 850d 34064 850f 34066 8511 OddHarmVbcxmrPct 15 min float ratio34068 8513 34070 8515 34072 8517 InterHarmVbcxmrPct 15 min float ratio34074 8519 34076 851b 34078 851d TotalHarmVbcxmrPct 15 min float ratio34080 851f 34082 8521 34084 8523 EvenHarmVcaxmrPct 15 min float ratio34086 8525 34088 8527 34090 8529 OddHarmVcaxmrPct 15 min float ratio34092 852b 34094 852d 34096 852f InterHarmVcaxmrPct 15 min float ratio34098 8531 34100 8533 34102 8535 TotalHarmVcaxmrPct 15 min float ratio34104 8537 34106 8539 34108 853b EvenHarmIaPct 15 min float ratio34110 853d 34112 853f 34114 8541 OddHarmIaPct 15 min float ratio34116 8543 34118 8545 34120 8547 InterHarmIaPct 15 min float ratio34122 8549 34124 854b 34126 854d TotalHarmIaPct 15 min float ratio34128 854f 34130 8551 34132 8553 EvenHarmIbPct 15 min float ratio34134 8555 34136 8557 34138 8559 OddHarmIbPct 15 min float ratio34140 855b 34142 855d 34144 855f InterHarmIbPct 15 min float ratio34146 8561 34148 8563 34150 8565 TotalHarmIbPct 15 min float ratio34152 8567 34154 8569 34156 856b EvenHarmIcPct 15 min float ratio34158 856d 34160 856f 34162 8571 OddHarmIcPct 15 min float ratio34164 8573 34166 8575 34168 8577 InterHarmIcPct 15 min float ratio34170 8579 34172 857b 34174 857d TotalHarmIcPct 15 min float ratio34176 857f 34178 8581 34180 8583 EvenHarmInPct 15 min float ratio34182 8585 34184 8587 34186 8589 OddHarmInPct 15 min float ratio34188 858b 34190 858d 34192 858f InterHarmInPct 15 min float ratio34194 8591 34196 8593 34198 8595 TotalHarmInPct 15 min float ratio

B.9. Latest Demand Profile Register Map

The following registers are organized in groups. Each row represents the latest energy demand profile value. The interval of the data is dictated by the configurable demand profile interval available in the meter configuration.



odbu

s R

egis

ter

Hex

Mod

bus

Reg

iste

r

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35000 88b8 Timestamp of most recent demand configurable Timestamp35006 88bd DemandIavg200RateE configurable float32_t A35008 88bf DemandPFwdRateE configurable float32_t W35010 88c1 DemandPRevRateE configurable float32_t W35012 88c3 DemandPNetRateE configurable float32_t W35014 88c5 DemandPSumRateE configurable float32_t W35016 88c7 DemandQFwdRateE configurable float32_t var35018 88c9 DemandQRevRateE configurable float32_t var35020 88cb DemandQNetRateE configurable float32_t var35022 88cd DemandQSumRateE configurable float32_t var35024 88cf DemandSRateE configurable float32_t VA

35026 88d1DemandCurrentMonthIavg200RateE-Peak configurable float32_t A

35028 88d3DemandCurrentMonthPFwdRateE-Peak configurable float32_t W

35030 88d5DemandCurrentMonthPNetRateE-Peak configurable float32_t W

35032 88d7DemandCurrentMonthPRevRateE-Peak configurable float32_t W

35034 88d9DemandCurrentMonthPSumRateE-Peak configurable float32_t W

35036 88dbDemandCurrentMonthQFwdRateE-Peak configurable float32_t var

35038 88ddDemandCurrentMonthQNetRateE-Peak configurable float32_t var

35040 88dfDemandCurrentMonthQRevRateE-Peak configurable float32_t var

35042 88e1DemandCurrentMonthQSumRateE-Peak configurable float32_t var

35044 88e3 DemandCurrentMonthSRateEPeak configurable float32_t VA35046 88e5 DemandCurrentIavg200RateEPeak configurable float32_t A35048 88e7 DemandCurrentPFwdRateEPeak configurable float32_t W35050 88e9 DemandCurrentPNetRateEPeak configurable float32_t W35052 88eb DemandCurrentPRevRateEPeak configurable float32_t W35054 88ed DemandCurrentPSumRateEPeak configurable float32_t W35056 88ef DemandCurrentQFwdRateEPeak configurable float32_t var35058 88f1 DemandCurrentQNetRateEPeak configurable float32_t var35060 88f3 DemandCurrentQRevRateEPeak configurable float32_t var35062 88f5 DemandCurrentQSumRateEPeak configurable float32_t var35064 88f7 DemandCurrentSRateEPeak configurable float32_t VA



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35066 88f9 AccCurrentITotalRateTotal configurable float32_t Ah35068 88fb AccCurrentPForwardRateTotal configurable float32_t Wh35070 88fd AccCurrentPNetRateTotal configurable float32_t Wh35072 88ff AccCurrentPReverseRateTotal configurable float32_t Wh35074 8901 AccCurrentPTotalRateTotal configurable float32_t Wh35076 8903 AccCurrentQFwdRateTotal configurable float32_t varh35078 8905 AccCurrentQNetRateTotal configurable float32_t varh35080 8907 AccCurrentQRevRateTotal configurable float32_t varh35082 8909 AccCurrentQTotalRateTotal configurable float32_t varh35084 890b AccCurrentSTotalRateTotal configurable float32_t VAh35086 890d DI_CounterDemand_One configurable float32_t35088 890f DI_CounterDemand_Two configurable float32_t35090 8911 DI_CounterDemand_Three configurable float32_t35092 8913 DI_CounterDemand_Four configurable float32_t35094 8915 DI_CounterDemand_Five configurable float32_t35096 8917 DI_CounterDemand_Six configurable float32_t35098 8919 DI_CounterDemand_Seven configurable float32_t35100 891b DI_CounterDemand_Eight configurable float32_t


C SNMP Communication

C SNMP COMMUNICATION

C.1. SNMP in Power Xpert Meter

The goal of the SNMP implementation in Power Meters is to help network managers to better manage a full and diverse set of Power Chain devices in their enterprise. This is achieved by providing, for all devices:A consistent view of each device with:• simple status information• basic descriptive information• highlighting of devices that require attention, with an indication of what sort of problem

is presentHistorical information (traps) that can be logged for event reconstruction:• sent when any device’s simple status changes • sent when alarms occur or clearThe MIBs supported are:

MIB filename Description / UsageEaton Power Xpert Meter MIB

EATON-PWR-MTR-MIB.txt

Metered electrical system values.

Eaton Alarms+Traps MIB EATON-PXG-MIB.txt Alarms and notifications (traps).Eaton Object Identifier (OID) assignments

EATON-OIDS.txt Base document for all OID as-signments for Eaton’s MIBs.

RFC 4133 Entity MIB ENTITY-MIB.txt Identification and description of each device

RFC 4268 Entity State MIB

ENTITY-STATE-MIB.txt Five availability status meters for each device attached to the card

RFC 4268 Entity State MIB Part 2

ENTITY-STATE-TC-MIB.txt

Possible state values for the Entity State MIB

The MIB files referenced above are available at the following Eaton web site URL: http://www.eaton.com/EatonCom/Markets/Electrical/Products/PowerQualityManagement/PowerXpertArchitecture/PowerXpertGatewaySeries1000Card/index.htm

You can add these files to the MIB database of your SMP management software toaccess the individual MIB objects.

MIB FILES

This section describes various the Management Information Base (MIB) files available. A MIB is an information repository residing on a device in a communication network. Network management software uses a device’s MIB to manage the device. Every man-ageable device on a network has a MIB consisting of one or more files that list information about the device. Use the facilities provided by your Simple Network Management Protocol (SNMP) man-agement software to access the individual MIB objects.

http://www.eaton.com/EatonCom/Markets/Electrical/Products/PowerQualityManagement/PowerXpertArchitecture/PowerXpertGatewaySeries1000Card/index.htm

http://www.eaton.com/EatonCom/Markets/Electrical/Products/PowerQualityManagement/PowerXpertArchitecture/PowerXpertGatewaySeries1000Card/index.htm


C SNMP Communication

You can configure a device so that it generates a trap if a certain condition occurs, such as an alarm clearing. The trap is sent to the management station to inform it of the occur-rence. See the MIB files for detailed information about each MIB object.


D Diagnostics

D DIAGNOSTICS

There are five Diagnostic screens; Battery Status, System Log, Event Count, Communications and I/O. These screens display the current health of the meter or a log of health related events. These screen have no user changeable fields. They display information only.

Locating Diagnostic Information on the Web

From the Setup Main Screen, click on Diagnostics from the tree structure on the left side of the screen. The tree structure will expand to list Battery Status, System Log, Event Log, Communica-tion and I/O. Click on the appropriate link. The screen will update to display the selected informa-tion.The following pages display the Diagnostic screens with a list of the information each provides.


D Diagnostics

D.1. Battery Status

• Battery Status - Good or Bad

The purpose of the battery (located on the core board) is to retain the real time clock through a power cycle. A status of “Bad” indicates that the real time clock has stopped because the battery no longer provides power.


D Diagnostics

D.2. System Log

• Power Fail Date and Time • Clear Log Date and Time*• Power Return Date and Time • Clear Trend Date and Time*• Setup Change Date and Time* • Clear Load Profile Date and Time*• Demand Reset Date and Time* • Clear Data Date and Time*• Energy Reset Date and Time* • Security - Log-in Failure Date and Time*• Min/Max Reset Date and Time* • Security - Log-in and Log-out Date and Time*• Reset Events Date and Time*

*User name is logged


D Diagnostics

D.3. Event Count

• Accumulator Rollovers• Demand Overload• Out of Limit Triggers• Fast Transient Triggers• ITIC Triggers


D Diagnostics

D.4. Communications - Ethernet Status

• IP Address• Subnet Mask• Default Gateway• MAC Address (CE)• Expansion Comms Ethernet Link Status • MAC address (CM) • Main Comms Ethernet Link Status

D.5. Communications - Ethernet Expansion Status

• Exp Comms MAC Address• Exp Comms Receive Bytes• Exp Comms Receive Packets• Exp Comms Receive Errors• Exp Comms Receive Drops• Exp Comms Receive FIFO Errors• Exp Comms Receive Frame Errors• Exp Comms Transmit Bytes • Exp Comms Transmit Packets• Exp Comms Transmit Errors• Exp Comms Transmit Drops• Exp Comms Transmit FIFO Errors• Exp Comms Transmit Collisions


D Diagnostics

D.6. Communications - COM0, COM1, COM2, COM3 (Slave)

• Messages Received• Errors• Exception Errors• Slave No Responses• Slave Naks• Slave Busy• Bus Character Overruns


D Diagnostics

D.7. Communications - COM1, COM2, COM3 (Master)

• Messages Sent• Messages Received• Errors• Slave No Responses• Slave Naks• Slave Busy• Bus Character Overruns


D Diagnostics


D Diagnostics

D.8. Communications - I/O Internal Input Status

• Present Status*• Status Change Count*

*For each digital input

D.9. Communications - I/O Internal Output Status

• Present Status*• Status Change Count*

*For each relay output


D Diagnostics


E Option Cards

E OPTION CARDS

The Power Xpert Meter can be equipped with option cards. This section describes the op-tional I/O-B and Communications Expansion cards that can be ordered with a new meter or as a field upgrade.

WARNINGSSHOCK HAZARDS: IMPROPER INSTALLATION CAN CAUSE DEATH, INJURY AND/OR EQUIPMENT DAMAGE. Completely read and understand the information in this document before attempting to install or operate the equipment. Improper installation could cause death, injury and/or equipment damage. Only qualified personnel are to service the Power Xpert Meter. Remove the input power (PSI) and verify that the health LED is no longer flashing before removing any option card. Do not remove any cards while the meter is energized.

FOR FIELD UPGRADE, DEENERGIZE EQUIPMENT. ENERGIZED (LIVE) ELECTRICAL WIRING AND/OR PARTS PRESENT THE HAZARD OF FATAL ELECTRIC SHOCK. Exercise extreme care to avoid injury or death. Always disconnect, lock-out and tag the current and voltage sources and the control power supply circuit before touching the con-nections or components on the rear face of the meter base unit.

FAILURE TO GROUND THE POWER XPERT METER MAY RESULT IN INJURY, DEATH OR EQUIPMENT DAMAGE. Properly ground the Power Xpert Meter during installation. A protective Earth grounding stud is located on the bottom right corner of the meter

CAUTION: AVOID ELECTROSTATIC DISCHARGE TO PREVENT EQUIPMENT DAMAGE. The Power Xpert Meter option cards are bare circuit boards with ESD sensitive components. The installer must follow proper ESD prevention techniques when handling the boards. Grounded wrist straps are recommended.Terminal Naming ConventionsThe naming of the terminal blocks follow circuit function and/or the association with the meter card name that they are located on. The metering inputs begin with CT, VT and Vx. The plug-in cards begin with IO, CE, CM and PS. On the plug-in modules, the separate terminal block group numberng starts at the top of the card and increases down the card. Individual terminals per block start with 1 and increase along the terminal block. The one exception is the V x auxillary terminal which increments on top of VT.


E Option Cards

E.1. Power Xpert Meter Option Cards

The Power Xpert Meter cards must be installed in their assigned slots due to the overlap-ping design of the terminal plates. The diagram below displays the correct placement for each card and the order in which each card must be disassembled or assembled when replacing cards.

Power Xpert Meter Card DefinitionsI/O PXMIO-B (Discrete Input/Output)CE PXMCE-B (Communication Expansion)CM PXMCM-1 (Communication Main)PS PXMPS-1 Power Supply Card

NOTE: Each terminal plate over-laps and fits together in specific order, requiring the correct disas-sembly and reassembly sequence.

3 2

2 3

1 4

CE CM PS

Disassembly order:

Assembly order:

4 1

I/O

NOTE: The option cards are bare circuit boards with ESD sensitive components. The installer must follow proper ESD prevention techniques when handling the boards. Grounded wrist straps are recommended.


E Option Cards

E.2. Optional I/O Card

The Power Xpert Meter can be equipped with an optional Discrete Input/Output (IO) card. The PXMIO-B card can be ordered with a new meter or as an field upgrade. This card includes 8 discrete inputs, 2 solid sate outputs, 3 relay outputs and a test LED. For field upgrade, de-energize equipment to prevent shock hazard. The meter includes sensitive electronic components. Caution should be used to avoid electrostatic discharge to prevent equipment damage.1. Disconnect control power and verify that the health LED is no longer flashing before

proceeding. 2. Remove power supply card after the health LED stops flashing3. Remove the main communications board and optional CE card or blank filler plate. 4. Carefully insert I/O card using card slot provided. Care should be taken that the card

alignment is correct before seating the card into the connector socket.5. Secure with screws at top and bottom. 6. Reassemble the CE card or blank filler plate and main communications and power sup-

ply, securing retaining screws on all cards.This card provides for external discrete I/O interfacing.

S1 LED Meter Test LED (Follows state of S1)

S1 Solid State Form A Output

S2 Solid State Form A Output

Max Load: 100mAMax Voltage: 30V

R1 Form C Relay OutputR1A Normally Open/R1B Normally Closed



240 VAC30Vdc Max 5 Amp

DI1 - DI8Discrete Inputs Self sourced: 24Vdc ~10mA/input

24Vdc Internal SourceDISDiscrete Input Source

6

PXMIO-B

5A

24

0V

AC

30

VD

C9

87

SELF SOU

RC

E2

4V

DC

54

32

IO3

-1

10

0m

A3

0V

DC

4IO

2-

32

16

98

75

34

1IO1

- 2

R2B

R3B

R3C

R3A

R2A

R2C

R1B

R1C

S21

R1A

S22

S12

S11

DI6

DIS

DI8

DI7

DI5

DI4

DI3

DI1

DI2

CW

S1 LED

10VA Source MAX

PXCM-5

TXDRXD

C

24+

SH

SH

DB

DA

CM

6-

32

1C

M5

-3

21

Com 0 Display

10VA Source MAX

C

24+

SH CM

4-

32

1

Com 1 RS485

TXDRXD

SH

DB

DA CM

3-

32

1

RXD/TXD10/100 T (RJ45)

Local ConfigurationLink

CM

1

CW

CE4

PXCE-B

100 Fx (ST)LAN/WAN

10/100 T (RJ45)TXD/RXD

Com 2 RS485

Link

Com 3 RS232

1C

E3-

23

DA

RXDTXD

DTE

TXD RXD

SH

DB

CE2

Tx

CE1

-

Rx

CW

AddressBase

1513

1

35

Health

11

CW

9

7

Status

ShortWarning!

unpluggingCT's before

CW

PS1

-100-240VAC

PXPS-1

110-250VDC50W Max47-63 Hz

21(+) L

(-) N

Rating

DO NOT HIPOT / DIELECTRIC TEST

AVERTISSEMENT: CET EQUIPEMENT RENFERME PLUSIEURS

REMOVE POWER BEFORE SERVICING3G

CIRCUITS SOUS TENSION. VOIR LE SCHEMA.

MORE THAN ONE LIVE CIRCUIT. SEE DIAGRAM.

WARNING

CW

for technical support

1-800-809-2772 or 1-414-449-7100

www.EatonElectrical.com

Customer Satisfaction

<http://www.EatonElectrical.com

2) THIS DEVICE MUST ACCEPT ANY INTERFERENCE RECEIVED,

THIS DEVICE COMPLIES WITH PART 15 OF THE FCC RULES.OPERATION IS SUBJECT TO THE FOLLOWING TWO CONDITIONS:1) THIS DEVICE MAY NOT CAUSE HARMFUL INTERFERENCE, AND

INCLUDING INTERFERENCE THAT MAY CAUSEUNDESIRED OPERATION.

E185559

MEASURING EQUIPMENT20NL


E Option Cards

IO1 - 8 Discrete Inputs to external dry contacts• IO11-IO18 ~ 10mA sink input• IO19 – 24V internal source for all inputs

IO2 – 2 Solid State relays – external source and load limited to 30VDC and 100mA.• IO21-I/O22 Solid State Output 1 (logic also tied to S1 LED )• IO23-I/O24 Solid State Output 2

IO3 – 3 Electro mechanical Relays rated for 240VAC/30VDC @ 5Amps• IO31 R1A - Form A contact Relay1• IO32 R1C - Common Relay 1• IO33 R1B - Form B contact Relay 1• IO34 R2A - Form A contact Relay2• IO35 R2C - Common Relay 2• IO36 R2B - Form B contact Relay 2• IO37 R3A - Form A contact Relay 3• IO38 R3C - Common Relay 3• IO39 R3B - Form B contact Relay 3

E.3. 1ms Time Stamping of Digital and Sub-Cycle Disturbance Events

The Power Xpert Meter is capable of time stamping digital and sub-cycle disturbance events to within +/- 1ms of the time of occurrence. The ability to time stamp digital input events and sub-cycle events with +/- 1ms accuracy can be invaluable when reconstructing the sequence of events in a forensic event analysis. In order to achieve +/- 1ms accuracy, the Power Xpert meter must be configured for one of two optional time sources.

E.4. NTP Time Server

Eaton offers the following time servers: • Power Xpert 100 Network Time Server (PX100NTSA) and the• Power Xpert 200 Network Time Server (PX200NTSA NTP)

depending on the application requirements. The Power Xpert Meter must be equipped with a Communications Expansion card in order to interface to the NTP Time Server. Eaton recommends that the NTP time server be installed on the same network drop as the Power Xpert Meters in order to optimize the accuracy of the meter time stamps for +/-1ms accuracy. The Power Xpert Meter should be configured for NTP as the clock source and the NTP server IP address must be configured in the communications setup page. Eaton recommends the use of an NTP server to synch the Power Xpert Meter for 1 ms time stamping applications to minimize wiring and installation costs.


E Option Cards

E.5. Satellite Time Reference (Cyber-Sciences STR-100)

For existing installations already equipped with a Satellite Time Reference (Cyber Sci-ences STR-100), the Power Xpert meter also accepts the DCF-77 time sync pulse stream. The STR-100 setup for DCF-77 pulse stream is only needed for the STR100 option. In order to use the STR-100 as a time reference, the Power Xpert Meter must be equipped with a PXIO-B card. One of the inputs on this card can be configured to accept the DCF-77 signal from the STR-100. In addition, the Power Xpert Meter clock must be configured for DCF-77 as the time source. A diagram of the electrical connection to the STR-100 out-put and the small isolation device used to isolate the Power Xpert input from the STR-100 output is displayed below.

+ G - 1 2 3 4

1 2 3 4 5 6 7 8 9 10 11 12

STR 100

A1+

A2- 13+

14

Phoenix ContactPLC-BSC-24DC/21

Internal 24Vdc Source

PXIO

PX Meter

E.1. PXIO-B

Power Xpert Meter


E Option Cards

E.6. Communications Expansion Card (PXMCE card)

The Power Xpert Meter can be equipped with a Communications Expansion card. The Communications Expansion card can be ordered with a new meter or as a field upgrade. This card includes a 100FX fiber port , a 10/100Base T RJ45, an RS485 and RS232 ports. The user must select either the 100FX fiber port or the 10/100Base T RJ45 port for the Ethernet network connection. This configuration option is described in the Setup chapter.For field upgrade, de-energize equipment. The Power Xpert Meter includes sensitive electronic components. Caution should be used to avoid electrostatic discharge to prevent equipment damage.

1. Remove the power supply and verify that the health LED is no longer illuminated before proceeding. Remove the main communications board.

2. Carefully insert Communication Expansion card using card slot provided. Care should be taken that the card alignment is correct before seating the card into the connector socket.

4. Reassemble cards in appropriate order, securing retaining screws on all cards.

CE

4

PXCE-B

100 Fx (ST)LAN/WAN

10/100 T (RJ45)TXD/RXD

Com 2 RS485

Link

Com 3 RS232

1C

E3

-2

3

DA

RXDTXD

DTE

TXD RXD

SH

DB

CE

2

Tx

CE

1-

Rx

CW

100FX ST-type Ethernet (multi-mode 62.5/125 µm)

10/100Base-T Ethernet RJ45

COM2 RS485Terminal Block CE3-

Terminals:CE3-3 SH RS485 ShieldCE3-2 DB RS485 Data B*CE3-1 DA RS485 Data A** Twisted pair

COM3 RS232 DB9 DTEConnector CE4

Pinout1 CD Carrier Detect2 RX Receive 3 TX Transmit4 DTR Data Terminal Ready5 GND Ground6 DSR Data Set Ready7 RTS Request To Send8 CTS Clear To Send9 RI Ring Indicator

CE Com 2 (Terminal CE 3)Each RS 485 link requires a set of fail safe bias re-sistors to guarrantee that the line goes to a marked state while the line is idle. The Power Xpert Meter convention is to set the 750 ohm bias resistors at the Master node only.The RS 485 Com port on the CE card defaults to Master Gateway function. The bias resistors are engaged via the jumper.Com 2 can be programmed alternatively to be a Slave Gateway or Modbus Slave RTU and there-fore would need the bias resistors dissengaged via jumpers onthe circuit board. To dissengage the bias reisitors, the CE board must be removed form the meter. See general card removal guidelines.Com 2 two bias jumpers, A and B; one for each data line. Both data lines should be treated the same.The jumper designators are stenciled as CN# with the following positions:

Jumper Setting: N=No Bias (slave); Rb=Bias (master)NOTE: Care should be taken to keep jumpers A and B set to the same value.

CE Com 3 Com 3 RS 232 port can be programmed to be a master or Slave Gateway or a Modbus slave RTU.

Note: The Power Xpert Meter must be equipped with a Communications Expansion card in order to interface to the NTP Time Server.


E Option Cards

E.7. Communication Ports (PXMCE card)

This optional Communication card allows for expanded networking capabilities of the me-ter. Note that the CE1 and CE2 Ethernet physical ports are connected to a common data channel. Only one of these can be used at a time. The card configuration is accessed via the local configuration port or the Display.CE1 - LAN/WAN Ethernet 100Fx - Fiber optic ST multimode cable (62.5/125um). IP address default set to DHCP and this physical interface disabled.

• CE11 Fx Rx• CE12 Fx Tx

CE2 - LAN/WAN Ethernet 10/100baseT Cat 5 (RJ45) interface. IP address set for DHCP and this physical port enabled.CE3 - COM2 – 3 terminal plug RS485 interface is configurable as Modbus RTU Slave or Gateway Master/Slave. Factory default setting is Master Gateway.

• CE31 Data A (-)• CE32 Data B (+)• CE33 Shield (RS485 common)

CE4 - COM3 - DTE DB9 RS232 interface is configurable as Modbus RTU Slave or Gate-way Master/Slave. Factory default setting is disabled.


E Option Cards

NOTE: Care should be taken to keep jumpers A and B set to the same value.

MasterN Rb

Rb N

Com 2 Jumpers

SlaveN Rb

Rb N

Jumper Setting

Jumper ID

AB

Com 2

Slave Port

NN

Master Port

RbRb


F Specifications

Compliance: Meter & Display

SafetyEN 61010-1CNL evaluation to CAN/C22.2 No 1010.1.92 UL 61010-1, 2nd Edition Display face, UL Validated to NEMA type 12, IP42 Meter & Display back, UL Validated to NEMA type 1, IP30

AccuracyIEC/EN 62053-22, Classes 0.2 & 0.5 (0.2% min)ANSI C12.20 (Electricity Meters 0.2%)

CE markElectromagnetic CompatibilityEmissions

FCC Part 15, Subpart B, Class A Radiated & ConductedEN55011 Class A Radiated & ConductedIEC 61000-3-2, EMC - Harmonic CurrentIEC 61000-3-3, EMC - Flicker - Low Voltage

Immunity - EN 61326, Industrial EMC Immunity EN 61000-4-2, ESD Level3EN 61000-4-3, Rad. RF Level 3EN 61000-4-4, EFT Level 3 EN 61000-4-5, Surge Level 3 (2 signal)EN 61000-4-6, Cond. RF Level 3EN 61000-4-11, Voltage Var.

EnvironmentalIEC 60529 Display face IP42 Display back IP30 Meter IP30IEC 60255-21-1, Vibration, Class 1IEC 60255-21-2, Shock/Bump, Class 1IEC 60255-21-3 Seismic, Class 1IEC 68-2-6, Vibration

Environmental Ratings - Meter and DisplayFor Indoor Use OnlyOperating Temperature Meter: -20° to 70°C (-4° to 158°F) - no rating restriction Display: -20° to 60°C Storage Temperature -40° to 85°C (-40° to 185°F)Humidity 5% - 95% (non-condensing) for all temperaturesMaximum Operating Altitude 3000 meters (6,561 feet)Pollution Degree II for Meter and Display BackPollution Degree III for Display Front Panel Housing must be => NEMA 12 or IP52 Panel must be flat to accept Display gasket Display Ethernet cover must be closed

F SPECIFICATIONS


F Specifications

Dimensions/Clearances/Weights MeterHeight: 8.32 inches Top/Bottom Clearance -3 inches minimum Clearance required for proper ventilationWidth: 8.2 inches Side clearance - 2 inches minimum Clearance required for proper access to termination Depth: with terminals and panel mounting feet - 6.8 inches Add 1.2 inch depth clearance for terminal plug field cable termination Add 3.2 inch depth clearance for RS232 or Fiber Optic Shipping Weight 7.1 lbs.Graphical DisplayHeight: Frame, 9.02 inches Body back, 7.22 inches Leave 2 inch top/bottom clearance for proper ventilationWidth: Frame, 7.77 inches Body back, 7.22 inches Depth: 2.54 inches total 1.4 inches from back of mounting panel back

Assumption panel = .125 in. thickness 1.04 inches from the front of mounting panel to tip of knob. Shipping Weight: 2.1 lbs.

Electrical SpecificationsDisplay Power Supply Input (DG2) 24 Vdc +/- 10% 8 W maximum draw Common TVS bonded to ground ~ 300V Wiring to 4 position removable terminal plug

12-18 AWG, wire ferrules recommended

Meter Power Supply InputPXMPS-1 Standard (PS1): 100 - 240 Vac +/- 20%, 47 - 63 Hz 110 - 250 Vdc +/- 20% 50W maximum draw Minimum Ride through 0.5 Sec Neutral (-) TVS bonded to ground ~ 575V Wiring to 3 position removable terminal plug


Meter PXMCM 24VDC outputs (CM4, CM6) 24VDC +/-10% 10W maximum load Output switched off on PS1 power down Common to paired RS485 port

CM3/CM4 CM5/CM6

Common TVS bonded to ground ~ 300V Wiring to 3 position removable terminal plug


Specifications, Con’t.


F Specifications

Meter PXMIO Discrete Inputs (IO1) Qty 8 common circuits IO1.1-1.8 24V internal source IO1.9

To drive external dry contact Input impedance ~ 2.2K ohm Input current draw ~ 10 mA Minimum pulse width 10 millisecond Maximum pulse rate 20 Hz Common TVS clamped to ground ~ 300V Wiring to 9 position removable terminal plug


Meter PXMIO Solid-State Outputs (IO2) Qty 2 – Form A NO Bidirectional FET Isolation Circuit to ground 2KV /1 min. Isolation SS1 to SS2 2KV / 1 min. Maximum external source voltage 30Vdc Line to Line TVS clamp at 32Vdc Maximum load current 100 mA. Minimum pulse width 20milliseconds

Fixed 25milliseconds for Pulse Initiator function Maximum pulse rate 25Hz Wiring to 4 position removable terminal plug


Meter PXMIO Relay Outputs (IO3) Qty 3 - Form C Relays (both NO=A and NC=B contacts) Rated Current Voltage 5 A/30 Vdc, 100 - 240 Vac Isolation circuit to ground 2,500 V / 1 minute Isolation Relay to Relay circuit 2,500 V / 1 minute Contacts MOV protected at ~300V Lifetime 5 A load 1,000,000 cycles Response Turn-On/Off Time ~ 20 - 30 msec Wiring to 9 position removable terminal plug

12-18 AWG, wire ferrules recommendedMetering inputs Current Inputs CT1-5 (Each channel)Rating 5 A secondary nominal, 20 A continuous maxMetering Range 0.05 to 20A Burden < 10 mohmOverload Withstand 500 A ac / 1 sec, non-repeatingAccuracy 0.05% of reading + .01% of full scale (50 mA to 20A)Wiring to removable terminal plug Screw down cover Range 10 AWG - 18 AWG Safety Insulation Rating 600 V all CT circuits to ground Installation Category CAT IIIDielectric Withstand All inputs to ground 3500 Vac / 1 minADC Conversion

30.72 ksps through delta-sigma A/D



F Specifications

True rms processing at 512 sample/cycle Delta sigma A/D oversampling rate: 4096 samples/cycle

Standard Metering Voltage Inputs VTV1-VRMaximum Rating 347 Vac rms L:G 600 Vac rms L:L Installation Category CAT -IIIMetering Range (Temporary transitions)

30-700 Vac rms L:GAbuse Overload Rating 1000 Vrms SustainedInput Impedance 2 megohmAccuracy 0.1% of reading + .02% of full scale 63-347 Vac rms L:GWiring to removable terminal plug Range 10 AWG - 18 AWGADC Conversion

30.72 ksps through delta-sigma A/D True rms processing at 512 sample/cycle Delta sigma A/D oversampling rate: 1024 samples/cycle

Auxiliary Voltage Inputs VXV6-V8 Maximum Rating 347 Vac rms L:G 600 Vac rms L:L Installation Category CAT -IIIMetering Range (Temporary transitions)

30-700 Vac rms L:GAbuse Overload Rating 1000 Vrms SustainedInput Impedance 2 megohmAccuracy 0.1% of reading + .02% of full scale 63-347 Vac rms L:GWiring to removable terminal plug Range 10 AWG - 18 AWGADC Conversion

30.72 ksps through delta-sigma A/D True rms processing at 512 sample/cycle All samples used in all rms calculations Delta sigma A/D oversampling rate: 4096 samples/cycle

High Speed Transient Voltage Inputs VTV1-VR(Parallel circuit to Standard Metering using the same terminal block.)Maximum Rating 347 Vac rms L:G 600 Vac rms L:L Installation Category CAT -IIIMetering Range (Temporary transitions- Surge/transients)

+/- 1-8000 Vpk L:GAbuse Overload Rating 1000 Vrms SustainedInput Impedance - 2 mega ohmAccuracy +/-1VWiring to removable terminal plug Range 10 AWG - 18 AWG



F Specifications

ADC Conversion 1 or 6 MHz

VT Standard/High Speed Inputs PT Potential Transformers RequirementsSingle PhaseNo PT required: 120 Vac L:N or 240 Vac L:L 277 Vac L:N or 554 Vac L:LPT required: Over 277 L:N or 554 Vac L:LWyeNo PT required: 120 Vac L:N or 208 Vac L:L 277 Vac L:N or 480 Vac L:L 347 Vac L:N or 600 Vac L:LPT required: Over 347 Vac L:N or 600 Vac L:LDeltaPT recommended: Up to 480 Vac L:LPT required: Over 480 Vac L:L

Optional VX Auxilary Input PT Potential Transformers RequirementsDeltaPT recommended: Up to 480 Vac L:LPT required: Over 480 Vac L:L Communication Main Termination Definition

COM 1 CM 3.1 Data A

CM 3.2 Data B

CM 3.3 Shield / Common

CM 4.1* Shield

CM 4.2* 24 V+ Source

CM 4.3* Common

COM 0 CM 5.1 Data A

CM 5.2 Data B

CM 5.3 Shield / Common

CM 6.1* Shield

CM 6.2* 24 V+ Source

CM 6.3* Comonm

COMMUNIC



F Specifications

Communication Expansion -Termination DefinitionCOM 2 CE 3.1 Data A (-)

CE 3.2 Data B (+)

CE 3.3 Shield / Common

Communication Expansion Card PXMCE

Port Connection Description LEDCE1 Ethernet Fiber ST LAN/WAN Uses LEDs on RJ45 RJ45 Ethernet CE2 Copper LAN/WAN Bottom Link Yellow / Top TX/RX - Bicolor

CE3 RS485 Com 2 TXD - Red / RXD - Green

CE4 RS232 Com 3 TXD - Red / RXD - Green

NICATION MAIN

Communication Main Card PXMCMort Connection Description LEDPort Connection Description LED CM1 RJ45 10/100 T (Local Configuration) Bottom Link Yellow / Top TX/RX - Bicolor CM3 Terminal Plug COM1 TXD - Red / RXD - GreenCM4 Terminal Plug Remote I/O Power CM5 Terminal Plug Display Link COM 0 TXD - Red / RXD - GreenCM6 Terminal Plug Display Power

ETHERNET PORTS

CM1

Specifications Description Data Rate 100/10 Mbps

Supported Protocols 192.168.1.1 fixed IP addresses support five concurrent connections

10/100 Base T

Isolation Transformer isolated Min. isolation voltage: 1,000 Vac 1 min.

Wire Type Equal or exceed 5 UTP Category 5 unshielded twisted pair recommended cable. Max. length: 100 meters Use of STP cable will yield improved EMI performance Connector Type Male RJ45 modular, Grounded Metal Shield



F Specifications

CE1, CE2

Specifications Description

Data Rate 100/10 Mbps Supported Protocols DHCP or fixed IP addresses and support five concurrent connections10/100 Base T

Isolation Transformer isolated

Min. isolation voltage: 1,000 Vac 1min.

Wire Type High quality 5 UTP Category 5 unshielded twisted pair recommended cable. Max. length: 100 meters Use of STP cable will yield improved EMI performance.

Connector Type Male RJ45 modular, Grounded Metal Shield

100 Fx (ST)

Isolation Optical Cable Type 62.5/125 micrometer multimode fiber cable. Max. length: 400 m Connector Type ST-type

Use Fiber Optic when distance and noise immunity leaving the gear is a concern.

RS-485

Com 0, Com 1, Com 2 **


Baud Rates 9600 - 115.2K

Duplex Half Supported Protocols Modbus gateway to other meters or a Modbus slave on a sub-network.


*Field circuit common is clamped to ground with TVS diode.


F Specifications

Isolation Optical isolation from all other inputs *and outputs, 240 Vac / 1 min. Cable Type Shielded Twisted Pair, 22 AWG

Max. Cable Length 4,000 feet

Twisted Pair Sensitivity Connect like data terminals

Star No

Tap No

End of Line Termination 100 - 120 ohms (match impedence of cable)

Max. number of devices 32 (The Display supports 16)

RS-232

Com 3


Baud Rates 9600 - 115.2K

Duplex Full

Supported Protocols Modbus Isolation Optical isolation from all other inputs *and outputs, 240 Vac / 1 min. Cable Type Shielded Twisted Pair, 22 AWG

Max. Cable Length 50 feet, DTE 9 pin dsub

*Field circuit common is clamped to ground with TVS diode at 300V.


G STANDARD CARDS

This chapter describes the standard Communication Main (CM) and Power Supply (PS) cards that are installed in all Power Xpert Meters.

WARNINGS

SHOCK HAZARDS: IMPROPER INSTALLATION CAN CAUSE DEATH, INJURY AND/OR EQUIPMENT DAMAGE. Completely read and understand the information in this document before attempting to install or operate the equipment. Improper installation could cause death, injury and/or equipment damage. Only qualified personnel are to service the Power Xpert Meter. Remove the input power (PSI) and verify that the health LED is no longer flash-ing before removing any option card. Do not remove any cards while the meter is energized. FOR FIELD UPGRADE, DE-ENERGIZE EQUIPMENT. ENERGIZED (LIVE) ELECTRI-CAL WIRING AND/OR PARTS PRESENT THE HAZARD OF FATAL ELECTRIC SHOCK. Exercise extreme care to avoid injury or death. Always disconnect, lock-out and tag the current and voltage sources and the control power supply circuit before touch-ing the connections or components on the rear face of the meter base unit. FAILURE TO GROUND THE POWER XPERT METER MAY RESULT IN INJURY, DEATH OR EQUIPMENT DAMAGE. Properly ground the Power Xpert Meter during installation. A protective Earth grounding stud is located on the bot-tom right corner of the meter.

CAUTION

AVOID ELECTROSTATIC DISCHARGE TO PREVENT EQUIPMENT DAMAGE. The Power Xpert Meter option cards are bare circuit boards with ESD sensitive compo-nents. The installer must follow proper ESD prevention techniques when handling the boards. Grounded wrist straps are recommended. Terminal Naming Conventions The naming of the terminal blocks follow circuit function and/or the association with the meter card name that they are located on. The metering inputs begin with CT, VT and Vx. The plug-in cards begin with IO, CE, CM and PS. On the plug-in mod-ules, the separate terminal block group numberng starts at the top of the card and increases down the card. Individual terminals per block start with 1 and increase along the terminal block. The one exception is the V x auxillary terminal which increments on top of VT.


G Standard Cards

Power Xpert Meter Card Definitions I/O PXMIO-B (Discrete Input/Output)

G.1. Power Xpert Meter Cards

The Power Xpert Meter cards must be installed in their assigned slots due to the overlapping design of the terminal plates. The diagram below displays the correct placement for each card and the order in which each card must be disassembled or assembled when they are replaced.

NOTE: The cards are bare circuit boards with ESD sensitive com-ponents. The installer must follow proper ESD prevention techniques when handling the boards. Ground-ed wrist straps are recommended. NOTE: Each terminal plate over-laps and fits together in specific order, requiring correct disassembly and reassembly sequence.

3 2

2 3

1 4

CE

Disassembly order:

Assembly order:

4 1

I/O

Page 264 IM02601004E www.eaton.com

G Standard Cards

The PXMCM card is the default communication card in all Power Xpert Meters. Configura-tion can be accessed via the CM local configuration port or the Display. CM1 – Local Configuration Port - Ethernet 10/100baseT RJ45 interface requires Cat 5 crossover cable. The IP address is fixed at 192.168.1.1 and is dedicated for configura-tion of the meter (including serial ports) with a PC browser. NOTE: This is NOT a LAN/WAN interface.

CM3 - COM1 – 3 terminal plug RS485 interface configurable as Modbus RTU Slave or Gateway Master/Slave. Defaults to slave Gateway. • CM31 Data A (-) • CM32 Data B (+) • CM33 Shield (RS485 common) CM4 - 24Vdc 10W max - 3 terminal, gender inverted plug. Source for use with auxiliary devices. (See following pages for further details.) NOTE: This output is electrically common with CM3/COM1. Do not extend cable be-yond 30M. • CM41 Shield • CM42 24V+

CM5 - COM0 - RS485 dedicated to remote Display interface for connection to DG1/ COM0 of the Display. The Meter address is assigned using the Rotary Switch found below the meter left side CT terminal.

• CM51 Data A (-) • CM52 Data B (+) • CM53 Shield (RS485 common)

CM6 - 24Vdc 10W max – Used to power the Graphical Display if the cable distance is less than 30M. If greater than 30M, use a separate 24V supply to power the Display. • CM61 Shield • CM62 24V+ • CM63 24V common

G.2. Communication Main (PXMCM) Card

Future Expansion


G Standard Cards

G.3. PXMCM Com 0 and Com 1 RS485 bias resistors (Terminals CM3, CM5)

Each RS485 link requires a set of fail safe bias resistors to guarantee that the line goes to a marked state while the line is idle. The meter convention is to set the 750 ohm bias resistors at the Master node only. • The RS485 Com ports on the PXMCM card default to Slave functions, therefore the factory default jumper postion is N for no bias. • Com 0 jumpers are set to N for use on the display’s network. • Com 1 can be programmed to be a Master Gateway. This requires changing the posi-tons of jumpers C1A and C1B from N to Rb. • To change the jumper position, the PXMCM board must be removed from the meter. See general card removal guidelines. • There are two bias resistors per port to bias each data line. Both jumpers should be set to the same position (N or Rb). • The jumpers designators are stenciled as C0 A and C0 B; C1A and C1B. Positions N are for not engaged and positions Rb are for engaged. See illustration on the following page. • Com 0 has jumpers C0 A and C0 B • Com 1 has jumpers C1A and C1B


G Standard Cards

Com 1 Jumpers

C1 B

Rb N

N Rb

Rb N

N Rb

PXMCM Com 0 and Com 1 RS485 bias resistors (Terminals CM3, CM5), Con’t.

Master Slave C1 B

Com 0

C1 A C1 A Com 1

NOTE: Care should be taken to keep jumpers A and B set to the same value.

Jumper Setting Jumper ID Slave PortMaster Port C0 A C0 B

N N

N/A N/A

C1 A C2 B

N N

Rb Rb


G Standard Cards

G.4. 24V Source Outputs CM4 & CM6

Note that the Outputs are color coded green and have gender inverted terminal plug header to prevent incorrect wiring with the communication ports. The maximum external load rating is 10W for each output. • The intended use for CM4 is to support external accessories • The intended use for CM6 is to support the graphical display PXD-MMG The wiring between the 24V source and the 24V load may not exceed 30M in length. • Beyond 30M, a separate external power supply must be supplied. • The power cable should be shielded with drain wire and the twisted power lines 18 -14 AWG. • Use ferrules to dress the power lines and prevent frayed wire shorting. The 24V outputs may NOT be used in parallel. The output power is common to the associ-ated RS485 circuit. • CM3/CM4 - RS485/Power are common. • CM5/CM6 - RS485/Power are common. • Care should be taken not to drive a voltage between the RS485 and power common. • A common communication and power cable can be used from the meter to the display. Belden 7895A or equivalent is recommended. Use Red/black pair for power, Blue/white pair for data The 24V outputs are turned on during power up. If during a voltage sag the input to the power supply is too low for normal operation, the CM4 and CM6 24V outputs are turned off to conserve ride through energy. This output drop will cause the display to cycle power and re-initialize after full voltage is restored.


G Standard Cards

• PS1 Power supply is sourced by either 100-240Vac or 110-250Vdc, 50W draw max. • PS11 Line (Vac) or (+) Vdc • PS12 Neutral (Vac) or (-)Vdc • PS13 ground

DIP Switch Configuration

The mode switches for the meter are located under a cover on the face of the PXPS-1 power supply. The meter reads the DIP switch settings during power-up. After making changes to the DIP switch, power must be cycled to the meter by removing and reapplying power to terminals PS1-1 and PS1-2. The switch cover supports a seal tab mecha-nism to prevent tampering with the meter mode. A second seal tab is located on the bottom of the power supply to allow for sealing the hardware configuration and restricting access.

DS -1

DS-2 DS-3

OFF OFF ON is Normal. OFF is Safe Mode

No restrictions (user ID/Password re-quired)

OFF ON ON is Normal. OFF is Safe Mode

Medium Security - Energy & Demand resets prohibited

ON OFF ON is Normal. OFF is Safe Mode

High Security- Configuration changes; Energy & Demand reset prohibited

ON ON ON or OFF

Factory Test Mode - The meter should never be operated in this mode. The meter will indicate that it’s in factory test mode through a repeating series of three flashes on the red Status LED.

G.5. Power Supply Card PXMPS-1

Power Supply Connections: The PXMPS-1 Standard power supply module powers the meter.


G Standard Cards

G.1. Diagnostic DIP Switch Settings

Should a problem arise with your meter, EATON support personnel may ask you to enable a diag-nostic mode using the DIP switches. When in diagnostic mode, Eaton personnel may instruct you to connect a laptop to the meter and either retrieve files or perform other tasks on the meter. The following shows the DIP switch configuration for diagnostic mode.

DS -1

DS-3

OFF OFF ON is Normal. OFF is Safe Mode

Diagnostic mode.


G Standard Cards


H Data Files

H DATA FILES

The Power Xpert Meter provides an FTP site, with anonymous access, that contains the following types of logs from the meter: • COMTRADE Files• Trend Logs (in .csv format). Because of the number of data fields that are recorded,

the trend logs are broken into three separate files.• Energy Logs (in .csv format)

H.1. Accessing the Files

Using an FTP client, such as Microsoft Internet Explorer, Filezilla, or the command line FTP utility, open FTP://ip_address

Where ip_address is the IP address of the meter.Note: If you use Internet Explorer, you can select Open FTP Site in Windows Explorer from the Page menu and use the familiar File Explorer to copy files down to your local computer.The FTP site has three directories: energy (energy logs), trend (trend logs), and wave-forms (COMTRADE files).

H.2. COMTRADE Files

The COMTRADE (Common Format for Transient Data) file format is an IEEE standard for storing and exchanging various types of transient electrical data. COMTRADE was developed for the power industry, and specifies such things as the sources of the data, sampling rate, and filters. A set of three files is required:• A header file (with a .hdr extension)• A configuration file (with a .cfg extension)• A data file (with a .dat extension)All three files are required for data exchange. The COMTRADE files store the following data:

Voltage Current Digital Input Channel*VAG IA DI1VBG IB DI2VCG IC DI3VNG IG DI4VAGAUX IN DI5VBGAUX DI6VCGAUX DI7

DI8RESERVED1RESERVED2*Waveforms (1 ms resolution) from digital inputs 1 through 8.


H Data Files

Voltage Current Digital Input Channel*RESERVED3*Waveforms (1 ms resolution) from digital inputs 1 through 8.

Note: for more information about digital input channels, see page 249. Capture waveform must be active for the input for data to be written to the file.The Power Xpert Software Quality Manager has a Waveform Viewer that can read COMTRADE files. You can use the Waveform Viewer to examine the waveform data in detail, as well as the metadata about each waveform. The following figure shows a COMTRADE file, taken from the meter, displayed in the Waveform Viewer.

ACCESSING THE COMTRADE FILES

COMTRADE file sets can be found in the waveforms directory of the meter’s anonymous FTP site. When copying these files to your local computer, make sure you get all three files in the set. Each file in a set has the same file name, such as wv00000001. The last characters of the filename are simply sequential numbers in hexadecimal, used to give each set unique filenames.

H.3. Energy Logs

Energy log file entries (rows) are captured in increments set for the Profile Interval on the Load Profile Setup screen. The default interval is 15 minutes. The log file format is a comma-separated values (CSV) file that can be readily loaded into Microsoft Excel, Micro-soft Access, or other spreadsheet, graphing, and database applications. The log files contain the following data fields:• Date• Time • Forward kW Demand • Reverse kW Demand • Net kW Demand • Sum kW Demand


H Data Files

• Received kvar Demand • Delivered kvar Demand • Net kvar Demand • Sum kvar Demand • kVA Demand • Forward kWh • Reverse kWh • Net kWh • Sum kWh • Received kvarh • Delivered kvarh • Net kvarh • Sum kvarh • kVAhwThe following figure shows a small portion of a typical energy log file in Microsoft Excel.

ACCESSING THE ENERGY LOGS

Energy log files are in the energy directory on the meter’s anonymous FTP site. The filename also contains a date stamp.

H.4. Trend Logs

Trend log file entries (columns) are captured in increments of five minutes, and this value can’t be changed. The log file format is a comma-separated values (CSV) file that can be readily loaded into Microsoft Excel or other spreadsheet, data analysis, or database applications. Because the meter logs so much data, the trend data is broken down into three separate files:• Trend_log_yyyymmdd.csv

• Trend_HarmMag_yyyymmdd.csv


H Data Files

• Trend_HarmPct_yyyymmdd.csv

Where yyyymmdd is a time stamp with the year, month, and day. The Trend_Log_yyyymmdd.csv contains all of the trend data except the harmonics data. The Trend_HarmMag_yyyymmdd.csv file contains all of the harmonic magnitude and fundamental magnitude data, whereas the the Trend_HarmPct_yyyymmdd.csv file contains all of the harmonic percentage data. For reference purposes, the following tables show the contents of each of the log files:

Trend_HarmMag_yyyymmdd.csv data fieldsDate Time EvenHarmonicIa(avg)EvenHarmonicIa(min) EvenHarmonicIa(max) EvenHarmonicIb(avg)EvenHarmonicIb(min) EvenHarmonicIb(max) EvenHarmonicIc(avg)EvenHarmonicIc(min) EvenHarmonicIc(max) EvenHarmonicIn(avg)EvenHarmonicIn(min) EvenHarmonicIn(max) EvenHarmonicVab(avg)EvenHarmonicVab(min) EvenHarmonicVab(max) EvenHarmonicVabxmr(avg)EvenHarmonicVabxmr(min) EvenHarmonicVabxmr(max) EvenHarmonicVan(avg)EvenHarmonicVan(min) EvenHarmonicVan(max) EvenHarmonicVbc(avg)EvenHarmonicVbc(min) EvenHarmonicVbc(max) EvenHarmonicVbcxmr(avg)EvenHarmonicVbcxmr(min) EvenHarmonicVbcxmr(max) EvenHarmonicVbn(avg)EvenHarmonicVbn(min) EvenHarmonicVbn(max) EvenHarmonicVca(avg)EvenHarmonicVca(min) EvenHarmonicVca(max) EvenHarmonicVcaxmr(avg)EvenHarmonicVcaxmr(min) EvenHarmonicVcaxmr(max) EvenHarmonicVcn(avg)EvenHarmonicVcn(min) EvenHarmonicVcn(max) FundamentalIa(avg)FundamentalIa(min) FundamentalIa(max) FundamentalIb(avg)FundamentalIb(min) FundamentalIb(max) FundamentalIc(avg)FundamentalIc(min) FundamentalIc(max) FundamentalIn(avg)FundamentalIn(min) FundamentalIn(max) FundamentalVab(avg)FundamentalVab(min) FundamentalVab(max) FundamentalVabxmr(avg)FundamentalVabxmr(min) FundamentalVabxmr(max) FundamentalVan(avg)FundamentalVan(min) FundamentalVan(max) FundamentalVbc(avg)FundamentalVbc(min) FundamentalVbc(max) FundamentalVbcxmr(avg)FundamentalVbcxmr(min) FundamentalVbcxmr(max) FundamentalVbn(avg)FundamentalVbn(min) FundamentalVbn(max) FundamentalVca(avg)FundamentalVca(min) FundamentalVca(max) FundamentalVcaxmr(avg)FundamentalVcaxmr(min) FundamentalVcaxmr(max) FundamentalVcn(avg)FundamentalVcn(min) FundamentalVcn(max) InterHarmonicIa(avg)InterHarmonicIa(min) InterHarmonicIa(max) InterHarmonicIb(avg)InterHarmonicIb(min) InterHarmonicIb(max) InterHarmonicIc(avg)InterHarmonicIc(min) InterHarmonicIc(max) InterHarmonicIn(avg)InterHarmonicIn(min) InterHarmonicIn(max) InterHarmonicVab(avg)InterHarmonicVab(min) InterHarmonicVab(max) InterHarmonicVabxmr(avg)InterHarmonicVabxmr(min) InterHarmonicVabxmr(max) InterHarmonicVan(avg)InterHarmonicVan(min) InterHarmonicVan(max) InterHarmonicVbc(avg)InterHarmonicVbc(min) InterHarmonicVbc(max) InterHarmonicVbcxmr(avg)InterHarmonicVbcxmr(min) InterHarmonicVbcxmr(max) InterHarmonicVbn(avg)InterHarmonicVbn(min) InterHarmonicVbn(max) InterHarmonicVca(avg)InterHarmonicVca(min) InterHarmonicVca(max) InterHarmonicVcaxmr(avg)


H Data Files

Trend_HarmMag_yyyymmdd.csv data fieldsInterHarmonicVcaxmr(min) InterHarmonicVcaxmr(max) InterHarmonicVcn(avg)InterHarmonicVcn(min) InterHarmonicVcn(max) OddHarmonicIa(avg)OddHarmonicIa(min) OddHarmonicIa(max) OddHarmonicIb(avg)OddHarmonicIb(min) OddHarmonicIb(max) OddHarmonicIc(avg)OddHarmonicIc(min) OddHarmonicIc(max) OddHarmonicIn(avg)OddHarmonicIn(min) OddHarmonicIn(max) OddHarmonicVab(avg)OddHarmonicVab(min) OddHarmonicVab(max) OddHarmonicVabxmr(avg)OddHarmonicVabxmr(min) OddHarmonicVabxmr(max) OddHarmonicVan(avg)OddHarmonicVan(min) OddHarmonicVan(max) OddHarmonicVbc(avg)OddHarmonicVbc(min) OddHarmonicVbc(max) OddHarmonicVbcxmr(avg)OddHarmonicVbcxmr(min) OddHarmonicVbcxmr(max) OddHarmonicVbn(avg)OddHarmonicVbn(min) OddHarmonicVbn(max) OddHarmonicVca(avg)OddHarmonicVca(min) OddHarmonicVca(max) OddHarmonicVcaxmr(avg)OddHarmonicVcaxmr(min) OddHarmonicVcaxmr(max) OddHarmonicVcn(avg)OddHarmonicVcn(min) OddHarmonicVcn(max) TotalHarmonicIa(avg)TotalHarmonicIa(min) TotalHarmonicIa(max) TotalHarmonicIb(avg)TotalHarmonicIb(min) TotalHarmonicIb(max) TotalHarmonicIc(avg)TotalHarmonicIc(min) TotalHarmonicIc(max) TotalHarmonicIn(avg)TotalHarmonicIn(min) TotalHarmonicIn(max) TotalHarmonicVab(avg)TotalHarmonicVab(min) TotalHarmonicVab(max) TotalHarmonicVabxmr(avg)TotalHarmonicVabxmr(min) TotalHarmonicVabxmr(max) TotalHarmonicVan(avg)TotalHarmonicVan(min) TotalHarmonicVan(max) TotalHarmonicVbc(avg)TotalHarmonicVbc(min) TotalHarmonicVbc(max) TotalHarmonicVbcxmr(avg)TotalHarmonicVbcxmr(min) TotalHarmonicVbcxmr(max) TotalHarmonicVbn(avg)TotalHarmonicVbn(min) TotalHarmonicVbn(max) TotalHarmonicVca(avg)TotalHarmonicVca(min) TotalHarmonicVca(max) TotalHarmonicVcaxmr(avg)TotalHarmonicVcaxmr(min) TotalHarmonicVcaxmr(max) TotalHarmonicVcn(avg)TotalHarmonicVcn(min) TotalHarmonicVcn(max)

Trend_HarmPct_yyyymmdd.csv data fieldsDate Time EvenHarmIaPct(avg)EvenHarmIaPct(min) EvenHarmIaPct(max) EvenHarmIbPct(avg)EvenHarmIbPct(min) EvenHarmIbPct(max) EvenHarmIcPct(avg)EvenHarmIcPct(min) EvenHarmIcPct(max) EvenHarmInPct(avg)EvenHarmInPct(min) EvenHarmInPct(max) EvenHarmVabPct(avg)EvenHarmVabPct(min) EvenHarmVabPct(max) EvenHarmVabxmrPct(avg)EvenHarmVabxmrPct(min) EvenHarmVabxmrPct(max) EvenHarmVanPct(avg)EvenHarmVanPct(min) EvenHarmVanPct(max) EvenHarmVbcPct(avg)EvenHarmVbcPct(min) EvenHarmVbcPct(max) EvenHarmVbcxmrPct(avg)EvenHarmVbcxmrPct(min) EvenHarmVbcxmrPct(max) EvenHarmVbnPct(avg)EvenHarmVbnPct(min) EvenHarmVbnPct(max) EvenHarmVcaPct(avg)EvenHarmVcaPct(min) EvenHarmVcaPct(max) EvenHarmVcaxmrPct(avg)EvenHarmVcaxmrPct(min) EvenHarmVcaxmrPct(max) EvenHarmVcnPct(avg)EvenHarmVcnPct(min) EvenHarmVcnPct(max) InterHarmIaPct(avg)


H Data Files

Trend_HarmPct_yyyymmdd.csv data fieldsInterHarmIaPct(min) InterHarmIaPct(max) InterHarmIbPct(avg)InterHarmIbPct(min) InterHarmIbPct(max) InterHarmIcPct(avg)InterHarmIcPct(min) InterHarmIcPct(max) InterHarmInPct(avg)InterHarmInPct(min) InterHarmInPct(max) InterHarmVabPct(avg)InterHarmVabPct(min) InterHarmVabPct(max) InterHarmVabxmrPct(avg)InterHarmVabxmrPct(min) InterHarmVabxmrPct(max) InterHarmVanPct(avg)InterHarmVanPct(min) InterHarmVanPct(max) InterHarmVbcPct(avg)InterHarmVbcPct(min) InterHarmVbcPct(max) InterHarmVbcxmrPct(avg)InterHarmVbcxmrPct(min) InterHarmVbcxmrPct(max) InterHarmVbnPct(avg)InterHarmVbnPct(min) InterHarmVbnPct(max) InterHarmVcaPct(avg)InterHarmVcaPct(min) InterHarmVcaPct(max) InterHarmVcaxmrPct(avg)InterHarmVcaxmrPct(min) InterHarmVcaxmrPct(max) InterHarmVcnPct(avg)InterHarmVcnPct(min) InterHarmVcnPct(max) OddHarmIaPct(avg)OddHarmIaPct(min) OddHarmIaPct(max) OddHarmIbPct(avg)OddHarmIbPct(min) OddHarmIbPct(max) OddHarmIcPct(avg)OddHarmIcPct(min) OddHarmIcPct(max) OddHarmInPct(avg)OddHarmInPct(min) OddHarmInPct(max) OddHarmVabPct(avg)OddHarmVabPct(min) OddHarmVabPct(max) OddHarmVabxmrPct(avg)OddHarmVabxmrPct(min) OddHarmVabxmrPct(max) OddHarmVanPct(avg)OddHarmVanPct(min) OddHarmVanPct(max) OddHarmVbcPct(avg)OddHarmVbcPct(min) OddHarmVbcPct(max) OddHarmVbcxmrPct(avg)OddHarmVbcxmrPct(min) OddHarmVbcxmrPct(max) OddHarmVbnPct(avg)OddHarmVbnPct(min) OddHarmVbnPct(max) OddHarmVcaPct(avg)OddHarmVcaPct(min) OddHarmVcaPct(max) OddHarmVcaxmrPct(avg)OddHarmVcaxmrPct(min) OddHarmVcaxmrPct(max) OddHarmVcnPct(avg)OddHarmVcnPct(min) OddHarmVcnPct(max) TotalHarmIaPct(avg)TotalHarmIaPct(min) TotalHarmIaPct(max) TotalHarmIbPct(avg)TotalHarmIbPct(min) TotalHarmIbPct(max) TotalHarmIcPct(avg)TotalHarmIcPct(min) TotalHarmIcPct(max) TotalHarmInPct(avg)TotalHarmInPct(min) TotalHarmInPct(max) TotalHarmVabPct(avg)TotalHarmVabPct(min) TotalHarmVabPct(max) TotalHarmVabxmrPct(avg)TotalHarmVabxmrPct(min) TotalHarmVabxmrPct(max) TotalHarmVanPct(avg)TotalHarmVanPct(min) TotalHarmVanPct(max) TotalHarmVbcPct(avg)TotalHarmVbcPct(min) TotalHarmVbcPct(max) TotalHarmVbcxmrPct(avg)TotalHarmVbcxmrPct(min) TotalHarmVbcxmrPct(max) TotalHarmVbnPct(avg)TotalHarmVbnPct(min) TotalHarmVbnPct(max) TotalHarmVcaPct(avg)TotalHarmVcaPct(min) TotalHarmVcaPct(max) TotalHarmVcaxmrPct(avg)TotalHarmVcaxmrPct(min) TotalHarmVcaxmrPct(max) TotalHarmVcnPct(avg)TotalHarmVcnPct(min) TotalHarmVcnPct(max)

Trend_log_yyyymmdd.csv Data FieldsDate Time FlickerPerceptSys(avg)FlickerPerceptSys(min) FlickerPerceptSys(max) PltVab(avg)PltVab(min) PltVab(max) PltVan(avg)


H Data Files

Trend_log_yyyymmdd.csv Data FieldsPltVan(min) PltVan(max) PltVbc(avg)PltVbc(min) PltVbc(max) PltVbn(avg)PltVbn(min) PltVbn(max) PltVca(avg)PltVca(min) PltVca(max) PltVcn(avg)PltVcn(min) PltVcn(max) PltVSys(avg)PltVSys(min) PltVSys(max) PstSys(avg)PstSys(min) PstSys(max) APFa(avg)APFa(min) APFa(max) APFb(avg)APFb(min) APFb(max) APFc(avg)APFc(min) APFc(max) APFsys(avg)APFsys(min) APFsys(max) CFa(avg)CFa(min) CFa(max) CFb(avg)CFb(min) CFb(max) CFc(avg)CFc(min) CFc(max) CFsys(avg)CFsys(min) CFsys(max) DPFa(avg)DPFa(min) DPFa(max) DPFb(avg)DPFb(min) DPFb(max) DPFc(avg)DPFc(min) DPFc(max) DPFsys(avg)DPFsys(min) DPFsys(max) FlickerPerceptVab(avg)FlickerPerceptVab(min) FlickerPerceptVab(max) FlickerPerceptVan(avg)FlickerPerceptVan(min) FlickerPerceptVan(max) FlickerPerceptVbc(avg)FlickerPerceptVbc(min) FlickerPerceptVbc(max) FlickerPerceptVbn(avg)FlickerPerceptVbn(min) FlickerPerceptVbn(max) FlickerPerceptVca(avg)FlickerPerceptVca(min) FlickerPerceptVca(max) FlickerPerceptVcn(avg)FlickerPerceptVcn(min) FlickerPerceptVcn(max) Fsys(avg)Fsys(min) Fsys(max) Ia200(avg)Ia200(min) Ia200(max) Iavg200(avg)Iavg200(min) Iavg200(max) Ib200(avg)Ib200(min) Ib200(max) Ic200(avg)Ic200(min) Ic200(max) IFa(avg)IFa(min) IFa(max) IFb(avg)IFb(min) IFb(max) IFc(avg)IFc(min) IFc(max) IFsys(avg)IFsys(min) IFsys(max) Ig200(avg)Ig200(min) Ig200(max) In200(avg)In200(min) In200(max) KFa(avg)KFa(min) KFa(max) KFb(avg)KFb(min) KFb(max) KFc(avg)KFc(min) KFc(max) KFsys(avg)KFsys(min) KFsys(max) NegSeqI(avg)NegSeqI(min) NegSeqI(max) NegSeqV(avg)NegSeqV(min) NegSeqV(max) NegSeqVxmr(avg)NegSeqVxmr(min) NegSeqVxmr(max) Pa(avg)


H Data Files

Trend_log_yyyymmdd.csv Data FieldsPa(min) Pa(max) Pb(avg)Pb(min) Pb(max) Pc(avg)Pc(min) Pc(max) PosSeqI(avg)PosSeqI(min) PosSeqI(max) PosSeqV(avg)PosSeqV(min) PosSeqV(max) PosSeqVxmr(avg)PosSeqVxmr(min) PosSeqVxmr(max) PstVab(avg)PstVab(min) PstVab(max) PstVan(avg)PstVan(min) PstVan(max) PstVbc(avg)PstVbc(min) PstVbc(max) PstVbn(avg)PstVbn(min) PstVbn(max) PstVca(avg)PstVca(min) PstVca(max) PstVcn(avg)PstVcn(min) PstVcn(max) Ptotal(avg)Ptotal(min) Ptotal(max) Qa(avg)Qa(min) Qa(max) Qb(avg)Qb(min) Qb(max) Qc(avg)Qc(min) Qc(max) Qtotal(avg)Qtotal(min) Qtotal(max) Sa(avg)Sa(min) Sa(max) Sb(avg)Sb(min) Sb(max) Sc(avg)Sc(min) Sc(max) Stotal(avg)Stotal(min) Stotal(max) Vab200(avg)Vab200(min) Vab200(max) Vabxmr200(avg)Vabxmr200(min) Vabxmr200(max) Van200(avg)Van200(min) Van200(max) Vbc200(avg)Vbc200(min) Vbc200(max) Vbcxmr200(avg)Vbcxmr200(min) Vbcxmr200(max) Vbn200(avg)Vbn200(min) Vbn200(max) Vca200(avg)Vca200(min) Vca200(max) Vcaxmr200(avg)Vcaxmr200(min) Vcaxmr200(max) Vcn200(avg)Vcn200(min) Vcn200(max) Vllavg200(avg)Vllavg200(min) Vllavg200(max) Vllavgxmr200(avg)Vllavgxmr200(min) Vllavgxmr200(max) Vlnavg200(avg)Vlnavg200(min) Vlnavg200(max) Vng200(avg)Vng200(min) Vng200(max) ZeroSeqI(avg)ZeroSeqI(min) ZeroSeqI(max) ZeroSeqV(avg)ZeroSeqV(min) ZeroSeqV(max) ZeroSeqVxmr(avg)ZeroSeqVxmr(min) ZeroSeqVxmr(max)

ACCESSING THE TREND LOG FILES

Trend log files are in the trend directory on the meter’s anonymous FTP site.


I Root Certificate Authority Installation

I ROOT CERTIFICATE AUTHORITY INSTALLATION

Improve the security of your Power Xpert Meter on the Web by installing a root certificate authority (CA). A CA is a trusted third-party organization that issues digital certificates for use with encrypted digital transactions. The digital certificate guarantees that the company holding a certificate is who it claims to be.You can use the meter without installing a root CA (using http), but the transactions will not be as secure as with the root CA (using https). The performance of the meter is not impacted by using secure transactions.This section explains root CA installation for:• Microsoft Internet Explorer 6• Microsoft Internet Explorer 7• Mozilla Firefox

I.1. Installing Root CA with Microsoft Internet Explorer 6 and 7

To install a certificate for the Power Xpert Meter with Microsoft Internet Explorer 6:1. Open the browser, type the IP address of the meter in the address bar, and select Go. For

example: https://192.168.1.1/ca.htmlThe install CA certificate page appears. (see Figure 1).

FIGURE 1. INSTALL CA CERTIFICATE PAGE

2. Click the Root CA Certificate link.3. Click the Open button.



FIGURE 2. FILE DOWNLOAD DIALOG BOX

4. In the Certificate dialog box, click the Install Certificate button.NOTE The certificate cannot be verified yet because it is issued by a nontrusted CA.FIGURE 3. CERTIFICATION PATH WINDOW

5. Click Install Certificate....The Certificate Import Wizard window opens (see Figure 4).



FIGURE 4. CERTIFICATE IMPORT WIZARD

6. Verify that the default setting, Automatically select the certificate store ..., is selected and then Click Next.

FIGURE 5. CERTIFICATE IMPORT WIZARD - SUCCESSFULLY STORED

7. The certificate wizard displays a completed dialog. Click Finish (see Figure 5).



FIGURE 6. SECURITY WARNING MESSAGE

8. Click Yes to install the CA.A new dialog box window opens to verify that the import was successful.

FIGURE 7. IMPORT SUCCESSFUL DIALOG BOX.

9. Click OK.10. Click OK to close the Certificate Window. The installation process is complete. You can now access the meter using the https protocol (for example, https://192.168.1.1/).

I.2. Installing Root CA with Mozilla Firefox

To install a certificate for the Power Xpert Meter with Mozilla Firefox:1. Open the browser and type the IP address of the meter followed by the path “/ca.html” in the

address bar. For example: https://192.168.1.1/ca.html2. The following page displays (see Figure 8):



FIGURE 8. MOZILLA FIREFOX

3. Click Root CA Certificate. Firefox opens the Downloading Certificate window (see Figure 9).

FIGURE 9. DOWNLOADING CERTIFICATE WINDOW

4. Click the Trust this CA to identify web sites check box option. 5. Click OK to complete the installation process.

The installation process is complete. You can now access the meter using the https protocol (for example, https://192.168.1.1/ca.html).

Eaton Corporation1000 Cherrington ParkwayMoon Township, PA 15108-4312United- StatesTel. 1--800-525-2000www. Eaton.com

© 2011 Eaton CorporationAll Rights ReservedPrinted in USAPublication No. IM02601004ENovember 2011

PowerChain Management is a registered trademark of Eaton Corporation.

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