Schneider Electric Marine Instruments PM810 User Guide

PowerLogic™ Series 800 Power Meter

PM810, PM820, PM850, & PM870

User Guide

63230-500-225A2

03/2011

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3/2011

PowerLogic Series 800 Power Meter

HAZARD CATEGORIES AND SPECIAL SYMBOLS

Read these instructions carefully and look at the equipment to become familiar with the

device before trying to install, operate, service, or maintain it. The following special

messages may appear throughout this bulletin or on the equipment to warn of potential

hazards or to call attention to information that clarifies or simplifies a procedure.

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

electrical hazard exists which will result in personal injury if the instructions are not

followed.

This is the safety alert symbol. It is used to alert you to potential personal injury hazards.

Obey all safety messages that follow this symbol to avoid possible injury or death.

DANGER

DANGER indicates an imminently hazardous situation which, if not

avoided, will result in death or serious injury.

WARNING

WARNING indicates a potentially hazardous situation which, if not

avoided, can result in death or serious injury.

CAUTION

CAUTION indicates a potentially hazardous situation which, if not

avoided, can result in minor or moderate injury.

CAUTION

CAUTION, used without the safety alert symbol, indicates a potentially

hazardous situation which, if not avoided, can result in property

damage.

NOTE: Provides additional information to clarify or simplify a procedure.

PLEASE NOTE

Electrical equipment should be installed, operated, serviced, and maintained only by

qualified personnel. No responsibility is assumed by Schneider Electric for any

consequences arising out of the use of this material.

CLASS A FCC STATEMENT

This equipment has been tested and found to comply with the limits for a Class A digital

device, pursuant to part 15 of the FCC Rules. These limits are designed to provide

reasonable protection against harmful interference when the equipment is operated in a

commercial environment. This equipment generates, uses, and can radiate radio frequency

energy and, if not installed and used in accordance with the instruction manual, may cause

harmful interference to radio communications. Operation of this equipment in a residential

area is likely to cause harmful interference in which case the user will be required to correct

the interference at his own expense. This Class A digital apparatus complies with Canadian

ICES-003.

iii

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PowerLogic Series 800 Power Meter

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PowerLogic^TMSeries 800 Power Meter

Contents

Chapter 1—Introduction - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 1

Topics Not Covered In This Manual - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 1

What is a Power Meter? - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 1

Power Meter Hardware - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 2

Box Contents - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 6

Features - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7

Firmware - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7

Chapter 2—Safety Precautions - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 9

Chapter 3—Operation - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11

Power Meter Display - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11

How the Buttons Work - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11

Changing Values - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11

Menu Overview - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11

Power Meter Setup - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 13

Power Meter Resets - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 23

Power Meter Diagnostics - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 25

Chapter 4—Metering Capabilities - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 27

Real-Time Readings - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 27

Power Factor Min/Max Conventions - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 28

Power Factor Sign Conventions - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 29

Demand Readings - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 30

Energy Readings - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 35

Energy-Per-Shift (PM810 with PM810LOG) - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 36

Power Analysis Values - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 37

Chapter 5—Input/Output Capabilities - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 39

Digital Inputs - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 39

Demand Synch Pulse Input - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 40

Relay Output Operating Modes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 40

Solid-state KY Pulse Output - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 42

Fixed Pulse Output - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 43

Calculating the Kilowatthour-Per-Pulse Value - - - - - - - - - - - - - - - - - - - - - - - - - - - 43

Analog Inputs - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 44

Analog Outputs - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 44

Chapter 6—Alarms - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 45

Basic Alarms - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 45

Basic Alarm Groups - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 45

Setpoint-driven Alarms - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 46

Priorities - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 47

Viewing Alarm Activity and History - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 47

Types of Setpoint-controlled Functions - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 47

Scale Factors - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 49

Scaling Alarm Setpoints - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 50

Alarm Conditions and Alarm Numbers - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 50

Advanced Alarms- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 53

Advanced Alarm Groups - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 53

Alarm Levels - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 54

Viewing Alarm Activity and History - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 54

Alarm Conditions and Alarm Numbers - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 55

Chapter 7—Logging - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 57

Introduction - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 57

Memory Allocation for Log Files - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 58

Alarm Log - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 58

Maintenance Log - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 58

Data Logs - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 60

Billing Log - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 61

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PowerLogic^TMSeries 800 Power Meter

Contents

63230-500-225A2

3/2011

Chapter 8—Waveform Capture - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -63

Introduction - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -63

Waveform Capture - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -63

Waveform Storage - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -64

How the Power Meter Captures an Event - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -64

Channel Selection in PowerLogic Software - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -64

Chapter 9—Disturbance Monitoring (PM870) - - - - - - - - - - - - - - - - - - - - - - - - - - - - -65

About Disturbance Monitoring - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -65

Capabilities of the PM870 During an Event - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -67

Chapter 10—Maintenance and Troubleshooting - - - - - - - - - - - - - - - - - - - - - - - - - -69

Introduction - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -69

Power Meter Memory - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -69

Identifying the Firmware Version, Model, and Serial Number - - - - - - - - - - - - - - - - -70

Viewing the Display in Different Languages - - - - - - - - - - - - - - - - - - - - - - - - - - - - -70

Technical Support - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -70

Troubleshooting - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -71

Appendix A—Instrument Transformer Wiring: Troubleshooting Tables - - - - - - - - 73

Using This Appendix - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -73

Section I: Common Problems for 3-Wire and 4-Wire Systems - - - - - - - - - - - - - - - -74

Section II: 3-Wire System Troubleshooting - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -75

Section III: 4-Wire System Troubleshooting - - - - - - - - - - - - - - - - - - - - - - - - - - - - -76

Field Example - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -78

Appendix B—Register List - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 79

About Registers - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -79

How Date and Time are Stored in Registers - - - - - - - - - - - - - - - - - - - - - - - - - - - - -80

How Signed Power Factor is Stored in the Register - - - - - - - - - - - - - - - - - - - - - - - -80

Supported Modbus Commands - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -81

Resetting Registers - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -81

Appendix C—Using the Command Interface- - - - - - - - - - - - - - - - - - - - - - - - - - - - - 83

Overview of the Command Interface - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -83

Operating Outputs from the Command Interface - - - - - - - - - - - - - - - - - - - - - - - - - -86

Using the Command Interface to Change Configuration Registers - - - - - - - - - - - - -86

Conditional Energy - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -87

Incremental Energy - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -88

Setting Up Individual Harmonic Calculations - - - - - - - - - - - - - - - - - - - - - - - - - - - - -89

Changing Scale Factors - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -90

Enabling Floating-point Registers - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -91

Appendix D—Advanced Power Quality Evaluations - - - - - - - - - - - - - - - - - - - - - - - 93

Power Quality Standards - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -93

SEMI-F47/ITI (CBEMA) Specification - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -93

EN50160:2000 Specification - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -95

How Evaluation Results Are Reported - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -95

Possible Configurations Through Register Writes - - - - - - - - - - - - - - - - - - - - - - - - -96

Evaluation During Normal Operation - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -96

Evaluations During Abnormal Operation - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -97

Operation with PQ Advanced Enabled - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -99

Advanced Power Quality Evaluation System Configuration

and Status Registers [EN50160 and SEMI-F47/ITI (CBEMA)] - - - - - - - - - - - - - - - -99

EN50160 Evaluation Data Available Over a Communications Link - - - - - - - - - - - -1 01

Setting Up PQ Advanced Evaluation from the Display - - - - - - - - - - - - - - - - - - - - -1 04

Glossary - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -1 05

Terms - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -1 05

Abbreviations and Symbols - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -1 07

Index - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -109

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PowerLogic^TMSeries 800 Power Meter

Chapter 1—Introduction

™

This user guide explains how to operate and configure a PowerLogic Series 800 Power

Meter. Unless otherwise noted, the information contained in this manual refers to the

following power meters:

•

Power meter with integrated display

Power meter without a display

Power meter with a remote display

Refer to “Power Meter Parts and Accessories” on page 5 for all models and model

numbers. For a list of supported features, see “Features” on page 7.

NOTE: The power meter units on the PM810, PM810U, and the PM810RD are functionally

equivalent.

Topics Not Covered In This Manual

Some of the power meter’s advanced features, such as on-board data logs and alarm log

files, can only be set up via the communications link using PowerLogic software. This

power meter user guide describes these advanced features but does not explain how to set

them up. For information on using these features, refer to your software’s online help or

user guide.

What is a Power Meter?

A power meter is a multifunction, digital instrumentation, data acquisition and control

device. It can replace a variety of meters, relays, transducers, and other components. This

power meter is equipped with RS485 communications for integration into any power

monitoring/control system and can be installed at multiple locations within a facility.

These are true rms meters, capable of exceptionally accurate measurement of highly

non-linear loads. A sophisticated sampling technique enables accurate measurements

➀

through the 63rd harmonic . You can view over 50 metered values, plus minimum and

maximum data, either from the display or remotely using software. Table 1–1 summarizes

the readings available from the power meter.

Table 1–1: Summary of power meter instrumentation

Real-time Readings

Power Analysis

•

Current (per phase, residual, 3-Phase)

Voltage (L–L, L–N, 3-Phase)

Real Power (per phase, 3-Phase

Reactive Power (per phase, 3-Phase

Apparent Power (per phase, 3-Phase

Power Factor (per phase, 3-Phase

Frequency

•

Displacement Power Factor (per phase, 3-Phase

Fundamental Voltages (per phase)

Fundamental Currents (per phase)

Fundamental Real Power (per phase)

Fundamental Reactive Power (per phase)

Unbalance (current and voltage)

Phase Rotation

THD (current and voltage)

Current and Voltage Harmonic Magnitudes and

➀

Angles (per phase)

•

Sequence Components

Energy Readings

Demand Readings

•

Accumulated Energy, Real

Accumulated Energy, Reactive

Accumulated Energy, Apparent

Bidirectional Readings

Reactive Energy by Quadrant

Incremental Energy

•

Demand Current (per phase present, 3-Phase

avg.)

Average Power Factor (3-Phase total)

Demand Real Power (per phase present, peak)

Demand Reactive Power (per phase present,

peak)

•

Conditional Energy

•

Demand Apparent Power (per phase present,

peak)

•

Coincident Readings

Predicted Power Demands

➀ Individual harmonics are not calculated in the PM810. The PM810 with PM810LOG, and the PM820,

calculate distortion to the 31st harmonic. The PM850 and PM870 calculate distortion to the 63rd harmonic.

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PowerLogic Series 800 Power Meter

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Chapter 1—Introduction

Power Meter Hardware

Power Meter With Integrated Display

Figure 1–1: Parts of the Series 800 Power Meter with integrated display

Bottom View

Back View

Table 1–2: Parts of the Series 800 Power Meter with integrated display

No. Part

Description

Control power supply connector

Connection for control power to the power meter.

Voltage metering connections.

Voltage inputs

I/O connector

Heartbeat LED

KY pulse output/digital input connections.

A green flashing LED indicates the power meter is ON.

The RS-485 port is used for communications with a monitoring and

control system. This port can be daisy-chained to multiple devices.

RS-485 port (COM1)

Option module connector

Current inputs

Used to connect an option module to the power meter.

Current metering connections.

Integrated display

Visual interface to configure and operate the power meter.

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PowerLogic^TMSeries 800 Power Meter

Chapter 1—Introduction

Power Meter Without Display

Figure 1–2: Parts of the Series 800 Power Meter without display

Bottom View

Back View

Table 1–3: Parts of the Series 800 Power Meter without display

No. Part Description

Control power supply connector

Connection for control power to the power meter.

Voltage metering connections.

Voltage inputs

I/O connector

Heartbeat LED

KY pulse output/digital input connections.

A green flashing LED indicates the power meter is ON.

The RS-485 port is used for communications with a monitoring and

control system. This port can be daisy-chained to multiple devices.

RS-485 port (COM1)

Option module connector

Current inputs

Used to connect an option module to the power meter.

Current metering connections.

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PowerLogic Series 800 Power Meter

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Chapter 1—Introduction

Power Meter With Remote Display

NOTE: The remote display kit (PM8RD) is used with a power meter without a display. See

“Power Meter Without Display” on page 3 for the parts of the power meter without a display.

Figure 1–3: Parts of the remote display and the remote display adapter

4 5 6 7 8

TX/RX

PM8RDA Top View

Table 1–4: Parts of the remote display

No. Part

Description

Provides the connection between the remote display and the

Remote display adapter (PM8RDA) power meter. Also provides an additional RS232/RS485

connection (2- or 4-wire).

Cable CAB12

Connects the remote display to the remote display adapter.

Visual interface to configure and operate the power meter.

Use to select the communications mode (RS232 or RS485).

Remote display (PM8D)

Communications mode button

When lit, the LED indicates the communications port is in RS232

mode.

Communications mode LED

This port is used for communications with a monitoring and control

system. This port can be daisy-chained to multiple devices.

RS232/RS485 port

Tx/Rx Activity LED

CAB12 port

The LED flashes to indicate communications activity.

Port for the CAB12 cable used to connect the remote display to

the remote display adapter.

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PowerLogic^TMSeries 800 Power Meter

Chapter 1—Introduction

Power Meter Parts and Accessories

Table 1–5: Power Meter Parts and Accessories

Model Number

Description

Schneider

Square D

Electric

Power meters

➀

➁

➂

➃

➀

➁

➂

➃

PM810

PM820

PM850

PM870

PM810MG

PM820MG

PM850MG

PM870MG

Power meter with integrated display

➀

PM810U

PM820U

PM850U

PM870U

PM810UMG

PM820UMG

PM850UMG

PM870UMG

➁

➂

➃

➁

➂

➃

Power meter without display

➀

➁

➂

➃

➀

➁

➂

➃

PM810RD

PM820RD

PM850RD

PM870RD

PM810RDMG

PM820RDMG

PM850RDMG

PM870RDMG

Power meter with remote display

Accessories

Remote display with remote display

adapter

PM8RD

PM8RDMG

Remote display adapter

PM8RDA

Input/Output modules

PM810 logging module

PM8M22, PM8M26, PM8M2222

PM810LOG

Cable (12 feet) extender kit for

displays

RJ11EXT

Retrofit gasket (for 4 in. round hole

mounting)

PM8G

CM2000 retrofit mounting adapter

PM8MA

➀ The power meter units for these models are identical and support the

same features (see “Features” on page 7).

➁ The power meter units for these models are identical and support the

same features (see “Features” on page 7).

➂ The power meter units for these models are identical and support the

same features (see “Features” on page 7).

➃ The power meter units for these models are identical and support the

same features (see “Features” on page 7).

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Chapter 1—Introduction

Box Contents

Table 1–6: Box contents based on model

Model Description

Box Contents

•

Power Meter with integrated display

Hardware kit (63230-500-16) containing:

— Two retainer clips

— Template

Power Meter with Integrated Display

— Plug set

— Terminator MCT2W

Power Meter installation guides (EN, FR, ES, DE)

•

Power Meter specification guide

•

Power Meter without display

Hardware kit (63230-500-16) containing:

— Two retainer clips

— Template

— DIN Slide (installed at factory)

— Plug set

Power Meter without Display

— Terminator MCT2W

Power Meter installation guides (EN, FR, ES, DE)

•

Power Meter specification guide

•

Power Meter without display

Remote display (PM8D)

Remote display adapter (PM8RDA)

Hardware kit (63230-500-16) containing:

— Two retainer clips

— Template

— DIN Slide (installed at factory)

— Plug set

— Terminator MCT2W

Power Meter with Remote Display

•

Hardware kit (63230-500-96) containing:

— Communication cable (CAB12)

— Mounting screws

Hardware kit (63230-500-163) containing:

— Com 2 RS-485 4-wire plug

— Crimp connector

•

Power Meter installation guides (EN, FR, ES, DE)

Power Meter specification guide

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PowerLogic^TMSeries 800 Power Meter

Chapter 1—Introduction

Features

Table 1–7: Series 800 Power Meter Features

PM810 PM820 PM850 PM870

True rms metering to the 63rd harmonic

Accepts standard CT and PT inputs

(3)



(3)



600 volt direct connection on voltage inputs

High accuracy — 0.075% current and voltage (typical conditions)

Min/max readings of metered data



Input metering (five channels) with PM8M22, PM8M26, or PM8M2222

installed



Power quality readings — THD



Downloadable firmware

Easy setup through the integrated or remote display (password protected)

Setpoint-controlled alarm and relay functions

On-board alarm logging

Wide operating temperature range: –25° to +70°C for the power meter

unit



Communications:

On-board: one Modbus RS485 (2-wire)

PM8RD: one configurable Modbus RS232/RS485 (2- or 4-wire)



Active energy accuracy: ANSI C12.20 Class 0.2S and IEC 62053-22

Class 0.5S



Non-volatile clock

(1)

(2)

On-board data logging

80 KB 800 KB 800 KB

Real-time harmonic magnitudes and angles (I and V):

To the 31st harmonic

(3)



—

To the 63rd harmonic



—

Waveform capture

Standard



—

Advanced

—

EN50160 evaluations

NOTE: The PM850 performs EN50160 evaluations based on

standard alarms, while the PM870 performs EN50160 evaluations

based on disturbance alarms.

—



ITI (CBEMA) and SEMI-F47 evaluations

—



NOTE: The PM870 performs ITI (CBEMA) and SEMI-F47

evaluations based on disturbance alarms.

Current and voltage sag/swell detection and logging

(1) The Time Clock in the PM810 with PM810LOG is non-volatile. However, it is volatile in the PM810.

(2) The on-board data logging memory in the PM810 with PM810LOG is 80 KB, but it is not available in the PM810.

(3) The PM810 with PM810LOG and the PM820 monitor distortion to the 31st harmonic. Harmonic distortion is not

monitored in the PM810.

Firmware

This user guide is written to be used with firmware version 11.xx and above. See

“Identifying the Firmware Version, Model, and Serial Number” on page 70 for instructions

on how to determine the firmware version. To download the latest firmware version, follow

the steps below:

1. Using a web browser, go to http://www.Schneider-Electric.com.

2. Locate the Search box in the upper right corner of the home page.

3. In the Search box enter “PM8”.

4. In the drop-down box click on the selection “PM800 series”.

5. Locate the downloads area on the right side of the page and click on

“Software/Firmware”.

6. Click on the applicable firmware version title (i.e. “PowerLogic Series 800 Power Meter

Firmware version 12.100”).

7. Download and run the “xxx.exe” firmware upgrade file provided.

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Chapter 1—Introduction

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PowerLogic^TMSeries 800 Power Meter

Chapter 2—Safety Precautions

DANGER

HAZARD OF ELECTRIC SHOCK, EXPLOSION OR ARC FLASH

• Apply appropriate personal protective equipment (PPE) and follow safe electrical

practices. For example, in the United States, see NFPA 70E.

• This equipment must only be installed and serviced by qualified electrical

personnel.

• NEVER work alone.

• Before performing visual inspections, tests, or maintenance on this equipment,

disconnect all sources of electric power. Assume that all circuits are live until they

have been completely de-energized, tested, and tagged. Pay particular attention to

the design of the power system. Consider all sources of power, including the

possibility of backfeeding.

• Turn off all power supplying this equipment before working on or inside equipment.

• Always use a properly rated voltage sensing device to confirm that all power is off.

• Beware of potential hazards and carefully inspect the work area for tools and

objects that may have been left inside the equipment.

• Use caution while removing or installing panels so that they do not extend into the

energized bus; avoid handling the panels, which could cause personal injury.

• The successful operation of this equipment depends upon proper handling,

installation, and operation. Neglecting fundamental installation requirements may

lead to personal injury as well as damage to electrical equipment or other property.

• Before performing Dielectric (Hi-Pot) or Megger testing on any equipment in which

the power meter is installed, disconnect all input and output wires to the power

meter. High voltage testing may damage electronic components contained in the

power meter.

• Always use grounded external CTs for current inputs.

Failure to follow these instructions will result in death or serious injury.

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PowerLogic^TMSeries 800 Power Meter

Chapter 3—Operation

This section explains the features of the power meter display and the power meter setup

procedures using this display. For a list of all power meter models containing an integrated

display or a remote display, see Table 1–5 on page 5.

Power Meter Display

The power meter is equipped with a large, back-lit liquid crystal display (LCD). It can

display up to five lines of information plus a sixth row of menu options. Figure 3–1 shows

the different parts of the power meter display.

Figure 3–1: Power Meter Display

A. Type of measurement

B. Screen title

C. Alarm indicator

D. Maintenance icon

E. Bar chart (%)

F. Units (A, V, etc.)

G. Display more menu items

H. Menu item

ꢑꢆꢒ

ꢂꢅꢀꢃꢆꢀꢄꢇꢆꢀꢁꢂꢃꢄ

ꢊ

ꢏꢏꢏꢏꢏꢐꢐꢐꢐꢐꢐ

ꢈꢖꢆꢆꢆꢆꢗꢖꢆꢆꢆꢈꢖꢖ

ꢀꢁꢂ

ꢀꢃꢂ

ꢀꢁꢄ

ꢂ

ꢓ

ꢔ

ꢂꢆ

ꢏꢏꢏꢏꢏꢐꢐꢐꢐꢐꢐ

ꢈꢖꢆꢆꢆꢆꢗꢖꢆꢆꢆꢈꢖꢖ

ꢂꢆ

ꢏꢏꢏꢏꢏꢐꢐꢐꢐꢐꢐ

ꢈꢖꢆꢆꢆꢆꢗꢖꢆꢆꢆꢈꢖꢖ

ꢂ

ꢘ

I. Selected menu indicator

J. Button

ꢀꢅꢃ

ꢕ

ꢂ

ꢆꢈꢉ

ꢀꢁꢂꢃꢄ ꢊꢆꢋꢅꢋꢌ ꢍꢍꢍꢎ

K. Return to previous menu

L. Values

M. Phase

How the Buttons Work

The buttons are used to select menu items, display more menu items in a menu list, and

return to previous menus. A menu item appears over one of the four buttons. Pressing a

button selects the menu item and displays the menu item’s screen. When you have

reached the highest menu level, a black triangle appears beneath the selected menu item.

To return to the previous menu level, press the button below 1;. To scroll through the menu

items in a menu list, press the button below ###:(see Figure 3–1).

NOTE: Each time you read “press” in this manual, press and release the appropriate button

beneath the menu item. For example, if you are asked to “Press PHASE,” you would press

the button below the PHASE menu item.

Changing Values

When a value is selected, it flashes to indicate that it can be modified. A value is changed

by doing the following:

•

Press +(plus) or -(minus) to change numbers or scroll through available options.

•

If you are entering more than a single-digit number, press <--to move to the next

higher numeric position.

•

To save your changes and move to the next field, press OK.

Menu Overview

Figure 3–2 on page 12, shows the first two levels of the power meter menu. Level 1

contains all of the top level menu items. Selecting a Level 1 menu item takes you to the

corresponding Level 2 menu items. Additional menu levels may be provided, depending on

the specific meter features and options.

NOTE: Press ###:to scroll through all menu items on a given level.

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Chapter 3—Operation

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Figure 3–2: Abbreviated List of PM800 Menu Items in IEEE (IEC) Mode

LEVEL 1

LEVEL 2

AMPS (I)

PHASE

I - DMD

UNBAL

V L-L (U)

V L-N (V)

VOLTS (U-V)

PWR (PQS)

ENERG (E)

PWR (PQS)

PHASE

VARh

P - DMD

VAh

INC

TRUE

DISPL

HZ (F)

THD

V L-L (U)

V L-N (V)

MINMX

AMPS (I)

V L-N (V)

VOLTS (U-V)

UNBAL

PWR (PQS)

HZ (F)

THD V

THD I

HARM

V L-L (U)

ALARM

I/O

ACTIV

D OUT

HIST

D IN

A OUT

A IN

PM8M2222

TIMER

CONTR

MAINT

RESET

SETUP

DIAG

METER

ENERG (E)

DMD

MINMX

MODE

TIMER

DATE

TIME

LANG

COMMS (COM)

METER

ALARM

I/O

PASSW

TIMER

ADVAN

COMM1

METER

REG

CLOCK

D OUT [Digital KY Out]

D IN [Digital In]

PM8RD

COMM2

PM8M2222, PM8M26, and PM8M22

PM8M2222

A OUT [Analog Out]

A IN

[Analog In]

➀ Available on the PM810 only when an optional Power Meter Logging Module (PM810LOG) is installed. Available on all other PM800 Series models.

➁ Available with some models.

➂ Both IEC and IEEE modes are available. Depending on the mode selected, menu labels will be different. See “Display Mode Change” on page 24 to select the

desired mode.

➃ The PM810 has a volatile clock. The PM810 with an optional Power Meter Logging Module (PM810LOG), and all other PM800 Series models, have a non-volatile

clock.

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PowerLogic^TMSeries 800 Power Meter

Chapter 3—Operation

Power Meter Setup

Power meter setup is typically performed by using the meter’s front panel display. To

configure a power meter without a display, you will need a means of communication

between the power meter and your computer. Additionally, you will need to install

PowerLogic Meter Configuration Software or PowerLogic ION Setup Software on your

computer. These can be downloaded from the Schneider’s www.Schneider-Electric.com

website.

Power meter setup is performed through the meter’s maintenance (MAINT) option. Refer to

Figure 3–2 on page 12. Setup features may be programmed individually or in any order. To

access the Setup features, follow these steps:

SETUP MODE Access

1. Press ###:to scroll through the Level 1 menu until you see MAINT.

2. Press MAINT.

3. Press SETUP.

4. Enter your password, then press OK. The SETUP MODE screen will be displayed.

NOTE: The default password is 0000.

5. Press ###:to scroll through the setup features and select the one to be programmed.

After programming a feature, you may continue through the remaining features by returning

to the SETUP MODE screen and pressing ###:to scroll to additional features.

Once you have selected the correct options for each setup parameter, press 1;until the

SAVE CHANGES? prompt appears, then press YES. The meter will reset, briefly display

the meter info screen, then automatically return to the main screen.

Use the menu provided in Figure 3–2 on page 12 to locate the setup features described in

the following topics:

DATE Setup

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

ꢋꢂꢚꢄꢆꢃꢄꢚꢛꢀ

2. Press ###:until DATE is visible.

3. Press DATE.

ꢆꢃ

ꢀꢁ

ꢅꢝꢕꢚꢁ

ꢋꢂꢟ

4. Enter the MONTH number.

5. Press OK.

6. Enter the DAY number.

7. Press OK.

ꢀꢆꢆꢄ

ꢆꢃꢇꢀꢁꢇꢆꢄ _{ꢅꢠꢋꢠꢟ}

ꢟꢄꢂꢇ

8. Enter the YEAR number.

9. Press OK.

ꢈꢉ

ꢙꢍ

ꢜ

ꢝꢞ

10. Select how the date is displayed: M/D/Y,

Y/M/D, or D/M/Y).

11. Press OK to return to the SETUP MODE

screen.

12. Press1;to return to the main screen.

13. To verify the new settings, press MAINT >

DIAG > CLOCK.

NOTE: The clock in the PM810 is volatile. Each time the meter resets, the PM810 returns

to the default clock date/time of 12:00 AM 01-01-1980. See “Date and Time Settings” on

page 69 for more information. All other PM800 Series meters have a non-volatile clock

which maintains the current date and time when the meter is reset.

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TIME Setup

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

ꢚꢊꢅꢄꢆꢃꢄꢚꢛꢀ

2. Press ###:until TIME is visible.

3. Press TIME.

ꢀꢁ

ꢁꢃ

ꢂꢈ

ꢁꢥꢦꢧ

ꢅꢊꢕ

4. Enter the HOUR.

5. Press OK.

6. Enter the MIN (minutes).

7. Press OK.

ꢃꢡꢢ

ꢣꢤꢁ

ꢝꢞ

8. Enter the SEC (seconds).

9. Press OK.

ꢈꢉ

ꢙꢍ

ꢜ

10. Select how the time is displayed: 24H or

AM/PM.

11. Press OK to return to the SETUP MODE

screen.

12. Press 1;to return to the main screen.

13. To verify the new settings, press MAINT >

DIAG > CLOCK.

NOTE: The clock in the PM810 is volatile. Each time the meter resets, the PM810 returns

to the default clock date/time of 12:00 AM 01-01-1980. See “Date and Time Settings” on

page 69 for more information. All other PM800 Series meters have a non-volatile clock,

which maintains the current date and time when the meter is reset.

LANG (Language) Setup

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

2. Press ###:until LANG is visible.

3. Press LANG.

ꢨꢂꢕꢩꢛꢂꢩꢄ

ꢄꢕꢩꢨꢌ

4. Select the language: ENGL (English), FREN

(French), SPAN (Spanish), GERMN (German),

or RUSSN (Russian).

5. Press OK.

6. At the SETUP MODE screen, continue

programming additional setup features or

press1;until you are asked to save changes.

ꢈꢉ

ꢙꢍ

ꢜ

ꢝꢞ

7. Press YES to save the changes.

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PowerLogic^TMSeries 800 Power Meter

Chapter 3—Operation

COMMS (Communications) Setup

NOTE: If you are using PowerLogic software to set up the power meter, it is recommended

you set up the communications features first.

Refer to Table 3-1 for the meter’s default settings.

Table 3–1: Communications Default Settings

Communications Setting

Default

Protocol

MB.RTU (Modbus RTU)

Address

Baud Rate

Parity

9600

Even

The same procedure is used to program the settings for the COMMS, COMM 1, and

COMM 2 options.

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

ꢔꢝꢅꢅꢃꢆꢃꢄꢚꢛꢀ

2. Press ###:until COMMS (communications)

is visible.

ꢅꢓꢌꢇꢚꢛ

3. Press COMMS (communications).

4. Select the required protocol: MB.RTU (Modbus

RTU), Jbus, MB. A.8 (Modbus ASCII 8 bits),

MB. A.7 (Modbus ASCII 7 bits).

ꢂꢋꢋꢇꢌ

ꢪꢫꢦꢋ

ꢆꢆꢉ

ꢊꢄꢆꢆ

5. Press OK.

ꢄꢬꢄꢕ

ꢝꢞ

6. Enter the ADDR (power meter address).

7. Press OK.

ꢈꢉ

ꢙꢍ

ꢜ

8. Select the BAUD (baud rate).

9. Press OK.

10. Select the parity: EVEN, ODD, or NONE.

11. Press OK.

12. At the SETUP MODE screen, continue

programming additional setup features or

press1;until you are asked to save changes.

13. Press YES to save the changes.

METER Setup

This feature allows the user to configure the CTs, PTs, system frequency, and system

wiring method.

CTs Setup

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

ꢔꢚꢆꢇꢂꢚꢊꢝ

2. Press ###:until METER is visible.

3. Press METER.

4. Press CT.

ꢈꢆꢆ

ꢂ

ꢔꢆꢚ

ꢀꢇꢊꢅ

ꢃꢄꢔꢌ

5. Enter the PRIM (CT primary) number.

6. Press OK.

7. Enter the SEC. (CT secondary) number.

8. Press OK.

ꢈꢉ

ꢙꢍ

ꢜ

ꢝꢞ

9. At the SETUP MODE screen, continue

programming additional setup features or

press1;until you are asked to save changes.

10. Press YES to save the changes.

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Chapter 3—Operation

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PTs Setup

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

ꢀꢚꢆꢇꢂꢚꢊꢝ

2. Press ###:until METER is visible.

3. Press METER.

ꢭ

ꢉ

ꢉꢀꢆ

ꢃꢔꢂꢨꢄ

ꢀꢇꢊꢅ

4. Press PT.

5. Enter the SCALE value: x1, x10, x100, NO PT

(for direct connect).

ꢃꢄꢔꢌ

ꢝꢞ

6. Press OK.

7. Enter the PRIM (primary) value.

8. Press OK.

ꢈꢉ

ꢙꢍ

ꢜ

9. Enter the SEC. (secondary) value.

10. Press OK.

11. At the SETUP MODE screen, continue

programming additional setup features or

press1;until you are asked to save changes.

12. Press YES to save the changes.

HZ (System Frequency) Setup

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

ꢆꢆꢆꢒ

ꢃꢟꢃꢚꢄꢅꢆꢮꢧꢡꢯꢦꢡꢕꢢꢰ

2. Press ###:until METER is visible.

3. Press METER.

4. Press ###:until HZ is visible.

5. Press HZ.

ꢄꢆ

ꢁꢱ

6. Select the frequency.

7. Press OK.

ꢮꢇꢄꢲꢌ

ꢝꢞ

8. At the SETUP MODE screen, continue

programming additional setup features or

press1;until you are asked to save changes.

ꢈꢉ

ꢙꢍ

ꢜ

9. Press YES to save the changes.

SYS (System Type) Setup

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

ꢆꢆꢆꢒ

ꢳꢆꢀꢁꢂꢃꢄꢆꢃꢟꢃꢚꢄꢅ

2. Press ###:until METER is visible.

3. Press METER.

ꢃ

ꢁ

ꢴꢊꢇꢄ

ꢔꢚ

4. Press ###:until SYS is visible.

5. Press SYS.

6. Select your system (SYS) type (D) based on

the number of wires (A), the number of CTs (B),

and the number of voltage connections (either

direct connect or with PT) (C).

ꢀꢚ

ꢃꢆ

ꢍ

ꢃꢟꢃꢌ

ꢝꢞ

ꢈꢉ

ꢜ

7. Press OK.

8. At the SETUP MODE screen, continue

programming additional setup features or

press1;until you are asked to save changes.

9. Press YES to save the changes.

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PowerLogic^TMSeries 800 Power Meter

Chapter 3—Operation

ALARM (Alarms) Setup

There is an extensive list of meter error conditions

which can be monitored and cause an alarm.

ꢆꢆꢆꢒ

ꢝꢬꢄꢇꢆꢬꢂꢕ

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

ꢄꢕꢂꢓꢨꢌ

ꢁꢊꢩꢁ

2. Press ###:until ALARM is visible.

ꢀꢆꢇ

ꢈꢉ

3. Press ALARM.

4. Press <-or ->to select the alarm option you

ꢂꢓꢃꢝꢨ

want to edit.

5. Press EDIT.

ꢙꢍ

ꢜ

ꢝꢞ

6. Select to ENABL (enable) or DISAB (disable)

the alarm.

7. Press OK.

8. Select the PR (priority): NONE, HIGH, MED, or

LOW.

9. Press OK.

10. Select how the alarm values are displayed:

ABSOL (absolute value) or RELAT (percentage

relative to the running average).

ꢆꢆꢆꢒ

ꢝꢬꢄꢇꢆꢬꢂꢕ

11. Enter the PU VALUE (pick-up value).

12. Press OK.

ꢀꢆꢛ

ꢅꢂꢩꢌ

ꢉꢆꢆ

ꢉ

ꢀꢆꢛ

ꢋꢆꢝ

ꢈꢉ

ꢋꢄꢨꢂꢟ

13. Enter the PU DELAY (pick-up delay).

14. Press OK.

ꢃ

ꢅꢂꢩꢌ

ꢋꢄꢨꢂꢟ

ꢝꢞ

15. Enter the DO VALUE (drop-out value).

16. Press OK.

ꢃ

ꢜ

ꢙꢍꢍꢍꢍ

17. Enter the DO DELAY (drop-out delay).

18. Press OK.

19. Press 1;to return to the alarm summary

screen.

20. Press 1;to return to the SETUP MODE screen.

21. At the SETUP MODE screen, continue

programming additional setup features or

press1;until you are asked to save changes.

22. Press YES to save the changes.

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Chapter 3—Operation

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I/O (Input/Output) Setup

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

2. Press ###:until I/O is visible.

3. Press I/O.

ꢆꢆꢆꢒ

ꢞꢟ

ꢕꢝꢇꢅ

4. Press D OUT for digital output or D IN for digital

input, or press A OUT for analog output or A IN

for analog input. Use the ###:button to scroll

through these selections.

ꢆ

ꢀꢛꢨꢃꢄ

ꢚꢊꢅꢄꢇ

ꢄꢭꢚꢌ

NOTE: Analog inputs and outputs are available

only with the PM8222 option module.

ꢈꢉ

ꢙꢍ

ꢜ

ꢝꢞ

5. Press EDIT.

6. Select the I/O mode based on the I/O type and

the user selected mode: NORM., LATCH,

TIMED, PULSE, or END OF.

7. Depending on the mode selected, the power

meter will prompt you to enter the pulse weight,

timer, and control.

8. Press OK.

9. Select EXT. (externally controlled via

communications) or ALARM (controlled by an

alarm).

10. Press 1;to return to the SETUP MODE screen.

11. At the SETUP MODE screen, continue

programming additional setup features or

press1;until you are asked to save changes.

12. Press YES to save the changes.

PASSW (Password) Setup

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

ꢆꢆꢆꢒ

ꢀꢂꢃꢃꢴꢝꢇꢋꢆꢃꢄꢚꢛꢀ

ꢆꢆꢆꢆ

2. Press ###:until PASSW (password) is visible.

3. Press PASSW.

ꢃꢄꢚꢛꢀ

ꢋꢊꢂꢩꢌ

4. Enter the SETUP password.

5. Press OK.

6. Enter the DIAG (diagnostics) password.

7. Press OK.

ꢆꢆꢆꢆ

ꢄꢕꢄꢇꢩ

ꢆꢆꢆꢆ

ꢜ

ꢅꢕꢠꢅꢭ

ꢝꢞ

8. Enter the ENERG (energy reset) password.

9. Press OK.

ꢈꢉ

ꢙꢍ

10. Enter the MN/MX (minimum/maximum reset)

password.

11. Press OK.

12. At the SETUP MODE screen, continue

programming additional setup features or

press1;until you are asked to save changes.

13. Press YES to save the changes.

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PowerLogic^TMSeries 800 Power Meter

Chapter 3—Operation

TIMER (Operating Time Threshold) Setup

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

2. Press ###:until TIMER is visible.

3. Press TIMER.

ꢝꢀꢄꢇꢆꢚꢊꢅꢄꢆꢃꢄꢚꢛꢀ

ꢀ

ꢳꢍꢀ

ꢊꢌꢆꢂꢬꢩ

ꢂ

4. Enter the 3-phase current average.

ꢉ

NOTE: The power meter begins counting the

operating time whenever the readings are equal

to or above the average.

5. Press OK.

ꢈꢉ

ꢙꢍꢍꢍꢍ

ꢜ

ꢝꢞ

6. At the SETUP MODE screen, continue

programming additional setup features or

press1;until you are asked to save changes.

7. Press YES to save the changes.

ADVAN (Advanced) Power Meter Setup Features

The Advanced Feature set contains several items which need to be programmed. To

access these features, follow these steps:

After programming a feature, you may continue through the remaining features by returning

to the SETUP MODE screen and pressing ###:to scroll to additional features.

Once you have selected the correct options for each setup parameter, press 1;until the

SAVE CHANGES? prompt appears, then press YES. The meter will reset, briefly display

the meter info screen, then automatically return to the main screen.

ROT (Phase Rotation) Setup

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

ꢀꢁꢂꢃꢄꢆꢇꢥꢵꢫꢵꢶꢥꢕ

2. Press ###:until ADVAN (advanced setup) is

visible.

ꢂꢓꢔ

3. Press ADVAN.

4. Press ###:until ROT (phase rotation) is visible.

5. Press ROT.

6. Select the phase rotation: ABC or CBA.

7. Press OK.

ꢈꢉ

ꢙꢍ

ꢜ

8. At the SETUP MODE screen, continue

programming additional setup features or

press1;until you are asked to save changes.

9. Press YES to save the changes.

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Chapter 3—Operation

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E-INC (Incremental Energy Interval) Setup

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

ꢊꢕꢔꢇꢆꢄꢕꢄꢇꢩꢟ

2. Press ###:until ADVAN (advanced setup) is

visible.

3. Press ADVAN.

ꢄꢆ

ꢊꢕꢚꢬꢨ

4. Press ###:until E-INC (incremental energy) is

visible.

5. Press E-INC.

6. Enter the INTVL (interval). Range is 00 to 1440.

7. Press OK.

ꢈꢉ

ꢙꢍ

ꢜ

ꢝꢞ

8. At the SETUP MODE screen, continue

programming additional setup features or

press1;until you are asked to save changes.

9. Press YES to save the changes.

THD Calculation Setup

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

ꢚꢁꢋꢆꢔꢫꢷꢢꢦꢷꢫꢵꢶꢥꢕ

2. Press ###:until ADVAN (advanced setup) is

visible.

3. Press ADVAN.

ꢸꢦꢕꢋ

4. Press ###:until THD is visible.

5. Press THD.

6. Select the THD calculation: FUND or RMS.

7. Press OK.

ꢈꢉ

ꢙꢍ

ꢜ

8. At the SETUP MODE screen, continue

programming additional setup features or

press1;until you are asked to save changes.

9. Press YES to save the changes.

VAR/PF Convention Setup

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

ꢀꢮꢆꢔꢥꢕꢹꢡꢕꢵꢶꢥꢕ

2. Press ###:until ADVAN (advanced setup) is

visible.

3. Press ADVAN.

ꢶꢡꢡꢡ

4. Press ###:until PF is visible.

5. Press PF.

6. Select the Var/PF convention: IEEE or IEC.

7. Press OK.

ꢈꢉ

ꢙꢍ

ꢜ

8. At the SETUP MODE screen, continue

programming additional setup features or

press1;until you are asked to save changes.

9. Press YES to save the changes.

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PowerLogic^TMSeries 800 Power Meter

Chapter 3—Operation

Lock Resets Setup

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

ꢷꢥꢢꢺꢆꢇꢡꢻꢡꢵꢻꢼ

2. Press ###:until ADVAN (advanced setup) is

visible.

ꢕ

ꢟ

ꢀꢞꢌꢋꢅꢋ

ꢄꢕꢄꢇꢩ

3. Press ADVAN.

4. Press ###:until LOCK is visible.

5. Press LOCK.

ꢕ

ꢅꢽꢠꢾꢿ

ꢘ

6. Select Y (yes) or N (no) to enable or disable

resets for PK.DMD, ENERG, MN/MX, and

METER.

ꢅꢡꢵꢡꢧ

ꢝꢞ

ꢈꢉ

ꢙꢍꢍ

ꢜ

7. Press OK.

8. At the SETUP MODE screen, continue

programming additional setup features or

press1;until you are asked to save changes.

9. Press YES to save the changes.

Alarm Backlight Setup

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

ꢂꢨꢂꢇꢅꢆꢓꢂꢔꢞꢨꢊꢩꢁꢚꢼ

2. Press ###:until ADVAN (advanced setup) is

visible.

3. Press ADVAN.

ꢝꢕ

4. Press ###:until BLINK is visible.

5. Press BLINK.

6. Enter ON or OFF.

7. Press OK.

ꢈꢉ

ꢙꢍ

ꢜ

ꢝꢞ

8. At the SETUP MODE screen, continue

programming additional setup features or

press1;until you are asked to save changes.

9. Press YES to save the changes.

Bar Graph Setup

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

ꢓꢫꢧꢆꣀꢧꢫꣁꢁꢆꢻꢢꢫꢷꢡ

2. Press ###:until ADVAN (advanced setup) is

visible.

3. Press ADVAN.

4. Press ###:until BARGR is visible.

5. Press BARGR.

6. Press AMPS or PWR.

7. Select AUTO or MAN. If MAN is selected, press

OK and enter the %CT*PT and KW (for PWR)

or the %CT and A (for AMPS).

ꢈꢉ

ꢂꢅꢀꢃ

ꢀꢴꢇ

8. Press OK.

9. At the SETUP MODE screen, continue

programming additional setup features or

press1;until you are asked to save changes.

10. Press YES to save the changes.

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Chapter 3—Operation

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PQ Advanced Evaluation Setup

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

ꢀꢲꢆꢂꢋꢹꢫꢕꢆꢃꢄꢚꢛꢀ

2. Press ###:until ADVAN (advanced setup) is

visible.

ꢝꢕ

3. Press ADVAN.

4. Press ###:until PQADV is visible.

5. Press PQADV.

ꢕꢝꢅꢆꢬ

ꢀꢁꢆ

6. Select ON.

7. Press OK.

ꢈꢉ

ꢙꢍꢍꢍꢍ

ꢜ

ꢝꢞ

8. Change the nominal voltage (NOM V) value if

desired (the default is 230).

9. Press OK to return to the SETUP MODE

screen.

10. At the SETUP MODE screen, continue

programming additional setup features or

press1;until you are asked to save changes.

11. Press YES to save your changes and reset the

power meter.

Power Demand Configuration Setup

1. Perform steps 1 through 5 of the SETUP MODE

Access procedure on page 11.

ꢀꢥꣂꢡꢧꢆꢋꢅꢋꢆꢔꢝꢕꢮꢊꢩ

ꢀ

2. Press ###:until ADVAN (advanced setup) is

visible.

ꢇꢔꢨꢔꢞ

ꢊꢕꢚꢬꢨ

ꢃꢛꢓꢍꢊ

3. Press ADVAN.

ꢉꢂ

ꢉ

4. Press ###:until DMD is visible.

5. Press DMD (P-DMD, I-DMD).

6. Select the demand configuration. Choices are

COMMS, RCOMM, CLOCK, RCLCK, IENGY,

THERM, SLIDE, BLOCK, RBLCK, INPUT, and

RINPUT.

ꢈꢉ

ꢙꢍ

ꢜ

ꢝꢞ

7. Press OK.

8. Enter the INTVL (interval) and press OK.

9. Enter the SUB-I (sub-interval) and press OK.

10. At the SETUP MODE screen, continue

programming additional setup features or

press1;until you are asked to save changes.

11. Press YES to save the changes.

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PowerLogic^TMSeries 800 Power Meter

Chapter 3—Operation

Power Meter Resets

The Power Meter Resets Feature set contains several items. After resetting a feature, you

may continue through the remaining features by returning to the RESET MODE screen and

pressing ###:to scroll to additional features. Once you have reset the specific features,

press 1;until the display returns to the main screen.

Initialize the Power Meter

Initializing the power meter resets the energy

readings, minimum/maximum values, and

operating times. To initialize the power meter,

follow these steps:

ꢊꢕꢊꢚꢌꢆꢅꢄꢚꢄꢇꢆꢼ

1. Press ###:to scroll through the Level 1 menu

until you see MAINT.

2. Press MAINT.

3. Press RESET.

4. Press ###:until METER is visible.

5. Press METER.

ꢕꢝ

ꢟꢄꢃ

6. Enter the password (the default is 0000).

7. Press YES to initialize the power meter and to

return to the RESET MODE screen.

8. At the RESET MODE screen, continue

resetting additional features or press1;until

you return to the main screen.

NOTE: We recommend initializing the power meter

after you make changes to any of the following:

CTs, PTs, frequency, or system type.

Accumulated Energy Readings Reset

1. Press ###:to scroll through the Level 1 menu

until you see MAINT.

ꢇꢄꢃꢄꢚꢆꢄꢕꢄꢇꢩꢟꢆꢼ

2. Press MAINT.

3. Press RESET.

ꢂꢁꢃꢅꢉꢀ

ꢀꢂꢊꢅꢊꢆ

ꢋꢀꢃꢅꢄꢄ

ꢺꢴꣃ

4. Press ###:until ENERG is visible.

5. Press ENERG.

ꢺꢬꢂꢇꣃ

ꢺꢬꢂꣃ

6. Enter the password (the default is 0000).

7. Press YES to reset the accumulated energy

readings and to return to the RESET MODE

screen.

ꢆꢄꢇꢉꢆꢇꢆꢄ

ꢈꢖꢌꢗꢖꢂ

ꢟꢄꢃ

ꢕꢝ

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Chapter 3—Operation

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Accumulated Demand Readings Reset

1. Press ###:to scroll through the Level 1 menu

until you see MAINT.

ꢇꢄꢃꢄꢚꢆꢋꢄꢅꢂꢕꢋꢆꢼ

2. Press MAINT.

3. Press RESET.

ꢈ

ꢁ

ꢀꢺ

ꢺꢴ꣄

4. Press ###:until DMD is visible.

5. Press DMD.

ꢺꢬꢂꢇ꣄

ꢂꢅꢀꢆꢋ

6. Enter the password (the default is 0000).

ꢃꢀ

ꢆꢈꢇꢉꢆꢇꢆꢄ

7. Press YES to reset the accumulated demand

readings and to return to the RESET MODE

screen.

ꢈꢖꢌꢗꢖ

ꢟꢄꢃ

ꢕꢝ

Minimum/Maximum Values Reset

1. Press ###:to scroll through the Level 1 menu

until you see MAINT.

ꢇꢄꢃꢄꢚꢆꢅꢊꢕꢠꢅꢂꢭꢆꢼ

2. Press MAINT.

3. Press RESET.

4. Press ###:until MINMX is visible.

5. Press MINMX.

6. Enter the password (the default is 0000).

7. Press YES to reset the minimum/maximum

values and to return to the RESET MODE

screen.

ꢆꢈꢇꢉꢆꢇꢆꢄ

ꢈꢖꢌꢗꢖꢂ

ꢟꢄꢃ

ꢕꢝ

Display Mode Change

1. Press ###:to scroll through the Level 1 menu

until you see MAINT.

ꢇꢄꢃꢄꢚꢆꢋꢄꢮꢂꢛꢨꢚꢆꢼ

2. Press MAINT.

3. Press RESET.

4. Press ###:until MODE is visible.

5. Press MODE.

6. Press IEEE (default for Square D branded

power meters) or IEC (default for Schneider

Electric branded power meters) depending on

the operating mode you want to use.

ꢲꢛꢊꢚ

ꢊꢄꢄꢄ

ꢊꢄꢔ

NOTE: Resetting the mode changes the menu

labels, power factor conventions, and THD

calculations to match the standard mode selected.

To customize the mode changes, see the register

list.

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PowerLogic^TMSeries 800 Power Meter

Chapter 3—Operation

Accumulated Operating Time Reset

1. Press ###:to scroll through the Level 1 menu

until you see MAINT.

ꢇꢄꢃꢄꢚꢆꢝꢀꢄꢇꢆꢚꢊꢅꢄꢆꢼ

2. Press MAINT.

3. Press RESET.

ꢉꢀꢆ

ꢉꢉ

ꢋꢂꢟꢃ

4. Press ###:until TIMER is visible.

5. Press TIMER.

ꢁꢝꢛꢇꢃ

6. Enter the password (the default is 0000).

ꢃꢀ

ꢅꢊꢕꢃ

7. Press YES to reset the accumulated operating

time and to return to the RESET MODE screen.

ꢕꢝ

ꢟꢄꢃ

NOTE: The accumulated days, hours, and

minutes of operation are reset to zero when you

press YES.

Power Meter Diagnostics

To view the power meter’s model, firmware version, serial number, read and write registers,

or check the health status, you must access the HEALTH STATUS screen.

After viewing a feature, you may continue through the remaining features by returning to

the HEALTH STATUS screen and selecting one of the other options.

Once you have viewed the specific features, press 1;until the display returns to the main

screen.

HEALTH STATUS screen

ꢁꢄꢂꢨꢚꢁꢆꢃꢚꢂꢚꢛꢃ

NOTE: The wrench icon and the health status code

display when a health problem is detected. For

code 1, set up the Date/Time (see “DATE Setup”

and “TIME Setup” on pages 11 and 12). For other

codes, contact technical support.

ꢝꢞ

ꢈꢉ

ꢅꢄꢚꢄꢇ

ꢇꢄꢩꢌ

ꢔꢨꢝꢔꢞ

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Chapter 3—Operation

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View the Meter Information

1. Press ###:to scroll through the Level 1 menu

until you see MAINT.

ꢅꢄꢚꢄꢇꢆꢊꢕꢮꢝ

2. Press MAINT.

3. Press DIAG (diagnostics) to open the HEALTH

STATUS screen.

ꢈꢂꢆ

ꢉꢀꢅꢉꢆꢆ

ꢉꢆꢅꢋꢆꢆ

ꢀꢂꢆꢆꢆꢉꢊꢁ

ꢀꢆꢅ

ꢆꢆꢬ

ꢅꢝꢋꢄꢨ

ꢖꢌꢗꢌ

4. On the HEALTH STATUS screen, press

METER (meter information).

ꢆꢆꢬ

ꢈꢉ

ꢇꢄꢃꢄꢚ

ꢃꢌꢕꢌ

5. View the meter information.

6. Press ###:to view more meter information.

ꢙꢍ

ꢍꣅ

7. Press 1;to return to the HEALTH STATUS

screen.

NOTE: The wrench icon and the health status code

display when a health problem is detected. For

code 1, set up the Date/Time (see “DATE Setup”

and “TIME Setup” on pages 11 and 12). For other

codes, contact technical support.

Read and Write Registers

1. Press ###:to scroll through the Level 1 menu

until you see MAINT.

ꢇꢠꢴꢆꢇꢄꢩꢊꢃꢚꢄꢇ

ꢉꢆꢆꢆ

ꢆꢆꢆꢆꢆ

ꢆ

2. Press MAINT.

3. Press DIAG (diagnostics) to open the HEALTH

STATUS screen.

ꢇꢄꢩꢌ

ꢁꢄꢭ

ꢋꢄꢔ

4. On the HEALTH STATUS screen, Press REG

(register).

5. Enter the password (the default is 0000).

6. Enter the REG. (register) number that contains

the data you want to monitor.

ꢝꢞ

ꢈꢉ

ꢙꢍ

ꢜ

The register content will be displayed in both

HEX (hexadecimal) and DEC (decimal) values.

7. Press 1;to return to the HEALTH STATUS

screen.

NOTE: For more information about using registers,

see Appendix C—Using the Command Interface

on page 83.

View the Meter Date and TIme

1. Press ###:to scroll through the Level 1 menu

until you see MAINT.

ꢀꢅ꣆ꢆꢋꢂꢚꢄꢍꢚꢊꢅꢄ

ꢉꢉ

ꢃꢀ

ꢋ

ꢆꢀꢇꢀꢈꢇꢆꢄ

2. Press MAINT.

3. Press DIAG (diagnostics) to open the HEALTH

STATUS screen.

ꢀꢆꢅ

ꢆꢆꢬ

ꢁꢝꢛꢇ

ꢅꢊꢕ

4. On the HEALTH STATUS screen, press

CLOCK (current date and time).

ꢆꢆꢬ

ꢈꢉ

ꢃꢄꢔ

5. View the date and time.

ꢚꢛꢄꢃ

6. Press 1;to return to the HEALTH STATUS

screen.

ꢙꢍ

ꢍꣅ

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PowerLogic^TMSeries 800 Power Meter

Chapter 4—Metering Capabilities

Real-Time Readings

The power meter measures currents and voltages, and reports in real time the rms values

for all three phases and neutral. In addition, the power meter calculates power factor, real

power, reactive power, and more.

Table 4–1 lists some of the real-time readings that are updated every second along with

their reportable ranges.

Table 4–1: One-second, Real-time Readings

Real-time Readings

Current

Reportable Range

Per-Phase

0 to 32,767 A

0 to 100.0%

Neutral

3-Phase Average

% Unbalance

Voltage

Line-to-Line, Per-Phase

Line-to-Line, 3-Phase Average

Line-to-Neutral, Per-Phase

Line-to-Neutral, 3-Phase Average

% Unbalance

0 to 1,200 kV

0 to 100.0%

Real Power

Per-Phase

0 to ± 3,276.70 MW

3-Phase Total

Reactive Power

Per-Phase

0 to ± 3,276.70 MVAR

3-Phase Total

Apparent Power

Per-Phase

0 to ± 3,276.70 MVA

3-Phase Total

Power Factor (True)

Per-Phase

–0.002 to 1.000 to +0.002

3-Phase Total

Power Factor (Displacement)

Per-Phase

–0.002 to 1.000 to +0.002

3-Phase Total

Frequency

45–65 Hz

23.00 to 67.00 Hz

350–450 Hz

350.00 to 450.00 Hz

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Chapter 4—Metering Capabilities

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Min/Max Values for Real-time Readings

When certain one-second real-time readings reach their highest or lowest value, the power

meter saves the values in its non-volatile memory. These values are called the minimum

and maximum (min/max) values.

The power meter stores the min/max values for the current month and previous month.

After the end of each month, the power meter moves the current month’s min/max values

into the previous month’s register space and resets the current month’s min/max values.

The current month’s min/max values can be reset manually at any time using the power

meter display or PowerLogic software. After the min/max values are reset, the power meter

records the date and time. The real-time readings evaluated are:

•

Min/Max Voltage L-L

Min/Max Voltage L-N

Min/Max Current

Min/Max Voltage L-L, Unbalance

Min/Max Voltage L-N, Unbalance

Min/Max Total True Power Factor

Min/Max Total Displacement Power

Factor

•

Min/Max Reactive Power Total

Min/Max Apparent Power Total

Min/Max THD/thd Voltage L-L

Min/Max THD/thd Voltage L-N

Min/Max THD/thd Current

Min/Max Frequency

Min/Max Voltage N-ground

(see the note below)

•

Min/Max Real Power Total

•

Min/Max Current, Neutral

(see the note below)

NOTE: Min/Max values for Vng and In are not available from the display. Use the display to

read registers (see “Read and Write Registers” on page 26) or use PowerLogic software.

For each min/max value listed above, the power meter records the following attributes:

•

Date/Time of minimum value

Minimum value

Phase of recorded minimum value

•

Date/Time of maximum value

Maximum value

Phase of recorded maximum value

NOTE: Phase of recorded min/max only applies to multi-phase quantities.

NOTE: There are two ways to view the min/max values. 1- Use the power meter display to

view the min/max values since the meter was last reset. 2- Use PowerLogic software to

view a table with the instantaneous min/max values for the current and previous months.

Power Factor Min/Max Conventions

All running min/max values, except for power factor, are arithmetic minimum and maximum

values. For example, the minimum phase A-B voltage is the lowest value in the range 0 to

1200 kV that has occurred since the min/max values were last reset. In contrast, because

the power factor’s midpoint is unity (equal to one), the power factor min/max values are not

true arithmetic minimums and maximums. Instead, the minimum value represents the

measurement closest to -0 on a continuous scale for all real-time readings -0 to 1.00 to +0.

The maximum value is the measurement closest to +0 on the same scale.

Figure 4–1 shows the min/max values in a typical environment in which a positive power

flow is assumed. In the figure, the minimum power factor is -0.7 (lagging) and the maximum

is 0.8 (leading). Note that the minimum power factor need not be lagging, and the maximum

power factor need not be leading. For example, if the power factor values ranged from

-0.75 to -0.95, then the minimum power factor would be -0.75 (lagging) and the maximum

power factor would be -0.95 (lagging). Both would be negative. Likewise, if the power factor

ranged from +0.9 to +0.95, the minimum would be +0.95 (leading) and the maximum would

be +0.90 (leading). Both would be positive in this case.

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Figure 4–1: Power factor min/max example

Minimum

Power Factor

-.7 (lagging)

Maximum

Power Factor

.8 (leading)

Range of Power

Factor Value

Unity

1.00

Lead

(+)

Lag

(–)

-0

NOTE: Assumes a positive power flow

An alternate power factor storage method is also available for use with analog outputs and

trending. See “Using the Command Interface” on page 83 for the applicable registers.

Power Factor Sign Conventions

The power meter can be set to one of two power factor sign conventions: IEEE or IEC. The

Series 800 Power Meter defaults to the IEEE power factor sign convention. Figure 4–2

illustrates the two sign conventions. For instructions on changing the power factor sign

convention, refer to “ADVAN (Advanced) Power Meter Setup Features” on page 19.

Figure 4–2: Power factor sign convention

Reactive

Power In

Reactive

Power In

Quadrant

watts negative (–)

vars positive (+)

power factor (–)

watts positive (+)

vars positive (+)

power factor (+)

watts negative (–)

vars positive (+)

power factor (+)

watts positive (+)

vars positive (+)

power factor (–)

Reverse

Power Flow

Normal

Power Flow

Reverse

Power Flow

Normal

Power Flow

Real

Power

Real

Power

watts negative (–)

vars negative (–)

power factor (–)

watts positive (+)

vars negative (–)

power factor (+)

watts negative (–)

vars negative (–)

power factor (–)

watts positive (+)

vars negative (–)

power factor (+)

Quadrant

IEC Power Factor Sign Convention

IEEE Power Factor Sign Convention

Figure 4–3: Power Factor Display Example

ꢆꢆꢆꢁ

ꢚꢧꢦꢡꢆꢀꢮ

꣇

The power

ꢆꢅꢋꢂꢋ

ꢆꢅꢋꢆꢃ

ꢆꢅꢋꢃꢃ

ꢂ

ꢓ

ꢔ

factor sign is

visible next to

the power

factor reading.

꣇

ꢆꢅꢋꢁꢄ

ꢚꢝꢚꢂꢨ

ꢈꢉ

ꢚꢇꢛꢄ

ꢋꢀꢃꢀꢨ

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Demand Readings

The power meter provides a variety of demand readings, including coincident readings and

predicted demands. Table 4–2 lists the available demand readings and their reportable

ranges.

Table 4–2: Demand Readings

Demand Readings

Reportable Range

Demand Current, Per-Phase, 3Ø Average, Neutral

Last Complete Interval

Peak

0 to 32,767 A

Average Power Factor (True), 3Ø Total

Last Complete Interval

Coincident with kW Peak

Coincident with kVAR Peak

Coincident with kVA Peak

Demand Real Power, 3Ø Total

Last Complete Interval

Predicted

–0.002 to 1.000 to +0.002

0 to ± 3276.70 MW

0 to ± 3276.70 MVA

0 to ± 3276.70 MVAR

Peak

Coincident kVA Demand

Coincident kVAR Demand

Demand Reactive Power, 3Ø Total

Last Complete Interval

Predicted

0 to ± 3276.70 MVAR

0 to ± 3276.70 MVA

0 to ± 3276.70 MW

Peak

Coincident kVA Demand

Coincident kW Demand

Demand Apparent Power, 3Ø Total

Last Complete Interval

Predicted

0 to ± 3276.70 MVA

0 to ± 3276.70 MW

0 to ± 3276.70 MVAR

Peak

Coincident kW Demand

Coincident kVAR Demand

Demand Power Calculation Methods

Demand power is the energy accumulated during a specified period divided by the length of

that period. How the power meter performs this calculation depends on the method you

select. To be compatible with electric utility billing practices, the power meter provides the

following types of demand power calculations:

•

Block Interval Demand

Synchronized Demand

Thermal Demand

The default demand calculation is set to sliding block with a 15 minute interval. You can set

up any of the demand power calculation methods using PowerLogic software.

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Block Interval Demand

In the block interval demand method, you select a “block” of time that the power meter uses

for the demand calculation. You choose how the power meter handles that block of time

(interval). Three different modes are possible:

•

Sliding Block. In the sliding block interval, you select an interval from 1 to 60 minutes

(in 1-minute increments). If the interval is between 1 and 15 minutes, the demand

calculation updates every 15 seconds. If the interval is between 16 and 60 minutes, the

demand calculation updates every 60 seconds. The power meter displays the demand

value for the last completed interval.

•

Fixed Block. In the fixed block interval, you select an interval from 1 to 60 minutes (in

1-minute increments). The power meter calculates and updates the demand at the end

of each interval.

Rolling Block. In the rolling block interval, you select an interval and a sub-interval.

The sub-interval must divide evenly into the interval. For example, you might set three

5-minute sub-intervals for a 15-minute interval. Demand is updated at each sub-

interval. The power meter displays the demand value for the last completed interval.

Figure 4–4 below illustrates the three ways to calculate demand power using the block

method. For illustration purposes, the interval is set to 15 minutes.

Figure 4–4: Block Interval Demand Examples

Demand value is the

average for the last

completed interval

Calculation updates

every 15 or 60

seconds

15-minute interval

Time

(sec)

15 30 45 60 . . .

Sliding Block

Demand value is

the average for

the last

completed

interval

Calculation updates at

the end of the interval

15-minute interval

15-min

Time

(min)

Fixed Block

Demand value is

the average for

the last

Calculation updates at the end of

the sub-interval (5 minutes)

completed

interval

15-minute interval

Time

(min)

Rolling Block

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Synchronized Demand

The demand calculations can be synchronized by accepting an external pulse input, a

command sent over communications, or by synchronizing to the internal real-time clock.

•

Input Synchronized Demand. You can set up the power meter to accept an input such

as a demand synch pulse from an external source. The power meter then uses the

same time interval as the other meter for each demand calculation. You can use the

standard digital input installed on the meter to receive the synch pulse. When setting up

this type of demand, you select whether it will be input-synchronized block or input-

synchronized rolling block demand. The rolling block demand requires that you choose

a sub-interval.

•

Command Synchronized Demand. Using command synchronized demand, you can

synchronize the demand intervals of multiple meters on a communications network. For

example, if a PLC input is monitoring a pulse at the end of a demand interval on a utility

revenue meter, you could program the PLC to issue a command to multiple meters

whenever the utility meter starts a new demand interval. Each time the command is

issued, the demand readings of each meter are calculated for the same interval. When

setting up this type of demand, you select whether it will be command-synchronized

block or command-synchronized rolling block demand. The rolling block demand

requires that you choose a sub-interval. See Appendix C—Using the Command

Interface on page 83 for more information.

•

Clock Synchronized Demand (Requires PM810LOG). You can synchronize the

demand interval to the internal real-time clock in the power meter. This enables you to

synchronize the demand to a particular time, typically on the hour. The default time is

12:00 am. If you select another time of day when the demand intervals are to be

synchronized, the time must be in minutes from midnight. For example, to synchronize

at 8:00 am, select 480 minutes. When setting up this type of demand, you select

whether it will be clock-synchronized block or clock-synchronized rolling block demand.

The rolling block demand requires that you choose a sub-interval.

Thermal Demand

The thermal demand method calculates the demand based on a thermal response, which

mimics thermal demand meters. The demand calculation updates at the end of each

interval. You select the demand interval from 1 to 60 minutes (in 1-minute increments). In

Figure 4–5 the interval is set to 15 minutes for illustration purposes.

Figure 4–5: Thermal Demand Example

The interval is a window of time that moves across the timeline.

99%

90%

Last completed

demand interval

Time

(minutes)

15-minute

interval

15-minute

interval

Calculation updates at the end of each interval

Demand Current

The power meter calculates demand current using the thermal demand method. The

default interval is 15 minutes, but you can set the demand current interval between 1 and

60 minutes in 1-minute increments.

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Predicted Demand

The power meter calculates predicted demand for the end of the present interval for kW,

kVAR, and kVA demand. This prediction takes into account the energy consumption thus

far within the present (partial) interval and the present rate of consumption. The prediction

is updated every second.

Figure 4–6 illustrates how a change in load can affect predicted demand for the interval.

Figure 4–6: Predicted Demand Example

Predicted demand is updated every second.

Beginning

of interval

15-minute interval

Demand

for last

completed

interval

Predicted demand if load is

added during interval;

predicted demand increases

to reflect increase demand

Partial Interval

Demand

Predicted demand if no load

is added.

Time

1:00

1:06

1:15

Change in Load

Peak Demand

In non-volatile memory, the power meter maintains a running maximum for the kWD,

kVARD, and kVAD power values, called “peak demand.” The peak for each value is the

highest average reading since the meter was last reset. The power meter also stores the

date and time when the peak demand occurred. In addition to the peak demand, the power

meter also stores the coinciding average 3-phase power factor. The average 3-phase

power factor is defined as “demand kW/demand kVA” for the peak demand interval.

Table 4–2 on page 30 lists the available peak demand readings from the power meter.

You can reset peak demand values from the power meter display. From the Main Menu,

select MAINT > RESET > DMD. You can also reset the values over the communications

link by using software.

NOTE: You should reset peak demand after changes to basic meter setup, such as CT

ratio or system type.

The power meter also stores the peak demand during the last incremental energy interval.

See “Energy Readings” on page 35 for more about incremental energy readings.

Generic Demand

The power meter can perform any of the demand calculation methods, described earlier in

this chapter, on up to 10 quantities that you choose using PowerLogic software. For generic

demand, do the following:

•

Select the demand calculation method (thermal, block interval, or synchronized).

Select the demand interval (from 5–60 minutes in 1–minute increments) and select

the demand sub-interval (if applicable).

•

Select the quantities on which to perform the demand calculation. You must also

select the units and scale factor for each quantity.

For each quantity in the demand profile, the power meter stores four values:

•

Partial interval demand value

Last completed demand interval value

Minimum values (date and time for each is also stored)

Peak demand value (date and time for each is also stored)

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You can reset the minimum and peak values of the quantities in a generic demand profile

by using one of two methods:

•

Use PowerLogic software, or

Use the command interface.

Command 5115 resets the generic demand profile. See Appendix C—Using the

Command Interface on page 83 for more about the command interface.

Input Metering Demand

The power meter has five input pulse metering channels, but only one digital input. Digital

inputs can be added by installing one or more option modules (PM8M22, PM8M26, or

PM8M2222). The input pulse metering channels count pulses received from one or more

digital inputs assigned to that channel. Each channel requires a consumption pulse weight,

consumption scale factor, demand pulse weight, and demand scale factor. The

consumption pulse weight is the number of watt-hours or kilowatt-hours per pulse. The

consumption scale factor is a factor of 10 multiplier that determines the format of the value.

For example, if each incoming pulse represents 125 Wh, and you want consumption data in

watt-hours, the consumption pulse weight is 125 and the consumption scale factor is zero.

The resulting calculation is 125 x 10 , which equals 125 watt-hours per pulse. If you want

-3

the consumption data in kilowatt-hours, the calculation is 125 x 10 , which equals 0.125

kilowatt-hours per pulse.Time must be taken into account for demand data; so you begin by

calculating demand pulse weight using the following formula:

watt-hours 3600 seconds

pulse

second

--------------------------- ------------------------------------ ------------------

watts =



pulse

hour

If each incoming pulse represents 125 Wh, using the formula above you get 450,000 watts.

If you want demand data in watts, the demand pulse weight is 450 and the demand scale

factor is three. The calculation is 450 x 10 , which equals 450,000 watts. If you want the

demand data in kilowatts, the calculation is 450 x 10 , which equals 450 kilowatts.

NOTE: The power meter counts each input transition as a pulse. Therefore, an input

transition of OFF-to-ON and ON-to-OFF will be counted as two pulses. For each channel,

the power meter maintains the following information:

•

Total consumption

Last completed interval demand—calculated demand for the last completed interval.

Partial interval demand—demand calculation up to the present point during the interval.

Peak demand—highest demand value since the last reset of the input pulse demand.

The date and time of the peak demand is also saved.

•

Minimum demand—lowest demand value since the last reset of the input pulse

demand. The date and time of the minimum demand is also saved.

To use the channels feature, first use the display to set up the digital inputs (see “I/O

(Input/Output) Setup” on page 18). Then using PowerLogic software, you must set the I/O

operating mode to Normal and set up the channels. The demand method and interval that

you select applies to all channels.

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Energy Readings

The power meter calculates and stores accumulated energy values for real and reactive

energy (kWh and kVARh) both into and out of the load, and also accumulates absolute

apparent energy. Table 4–3 lists the energy values the power meter can accumulate.

Table 4–3: Energy Readings

Energy Reading, 3-Phase

Reportable Range

Shown on the Display

Accumulated Energy

Real (Signed/Absolute)

-9,999,999,999,999,999 to

9,999,999,999,999,999 Wh

Reactive (Signed/Absolute)

-9,999,999,999,999,999 to

9,999,999,999,999,999 VARh

0000.000 kWh to 99,999.99 MWh

and

Real (In)

0 to 9,999,999,999,999,999 Wh

0 to 9,999,999,999,999,999 VARh

0 to 9,999,999,999,999,999 VAh

Real (Out)

0000.000 to 99,999.99 MVARh

Reactive (In)

Reactive (Out)

Apparent

Accumulated Energy, Conditional

Real (In)

0 to 9,999,999,999,999,999 Wh

0 to 9,999,999,999,999,999 VARh

0 to 9,999,999,999,999,999 VAh

These values not shown on the

display. Readings are obtained

only through the communications

link.

Real (Out)

Reactive (In)

Reactive (Out)

Apparent

Accumulated Energy, Incremental

Real (In)

0 to 999,999,999,999 Wh

0 to 999,999,999,999 VARh

0 to 999,999,999,999 VAh

These values not shown on the

display. Readings are obtained

only through the communications

link.

Real (Out)

Reactive (In)

Reactive (Out)

Apparent

Reactive Energy

Quadrant 1

0 to 999,999,999,999 VARh

These values not shown on the

display. Readings are obtained

only through the communications

link.

Quadrant 2

Quadrant 3

Quadrant 4

➀ Not shown on the power meter display.

The power meter can accumulate the energy values shown in Table 4–3 in one of two

modes: signed or unsigned (absolute). In signed mode, the power meter considers the

direction of power flow, allowing the magnitude of accumulated energy to increase and

decrease. In unsigned mode, the power meter accumulates energy as a positive value,

regardless of the direction of power flow. In other words, the energy value increases, even

during reverse power flow. The default accumulation mode is unsigned.

You can view accumulated energy from the display. The resolution of the energy value will

automatically change through the range of 000.000 kWh to 000,000 MWh (000.000 kVAh

to 000,000 MVARh), or it can be fixed. See Appendix C—Using the Command Interface

on page 83 for the contents of the registers.

For conditional accumulated energy readings, you can set the real, reactive, and apparent

energy accumulation to OFF or ON when a particular condition occurs. You can do this over

the communications link using a command, or from a digital input change. For example,

you may want to track accumulated energy values during a particular process that is

controlled by a PLC. The power meter stores the date and time of the last reset of

conditional energy in non-volatile memory.

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The power meter also provides an additional energy reading that is only available over the

communications link:

•

Four-quadrant reactive accumulated energy readings. The power meter

accumulates reactive energy (kVARh) in four quadrants as shown in Figure 4–7. The

registers operate in unsigned (absolute) mode in which the power meter accumulates

energy as positive.

Figure 4–7: Reactive energy accumulates in four quadrants

Reactive

Power In

Quadrant

watts negative (–)

vars positive (+)

watts positive (+)

vars positive (+)

Reverse

Normal

Power Flow

Real

Power

Power Flow

watts negative (–)

vars negative (–)

watts positive (+)

vars negative (–)

Quadrant

Energy-Per-Shift (PM810 with PM810LOG)

The energy-per-shift feature allows the power meter to group energy usage based on three

groups: 1st shift, 2nd shift, and 3rd shift. These groups provide a quick, historical view of

energy usage and energy cost during each shift. All data is stored in non-volatile memory.

Table 4–4: Energy-per-shift recorded values

Category

Recorded Values

•

Today

Yesterday

This Week

Last Week

This Month

Last Month

Time Scales

•

Real

Apparent

Energy

•

Today

Yesterday

This Week

Last Week

This Month

Last Month

Energy Cost

•

Meter Reading Date

Meter Reading Time of Day

1st Day of the Week

User Configuration

Configuration

The start time of each shift is configured by setting registers using the display or by using

PowerLogic software. Table 4-5 summarizes the quantities needed to configure energy-

per-shift using register numbers.

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Table 4–5: Energy-per-shift recorded values

Quantity

Description

For each shift, enter the minutes from

midnight at which the shift starts.

•

1st shift: 16171

2nd shift: 16172

3rd shift: 16173

Defaults:

Shift Start Time

1st shift = 420 minutes (7:00 am)

2nd shift = 900 minutes (3:00 pm)

3rd shift = 1380 minutes (11:00 pm)

•

1st shift: 16174

2nd shift: 16175

3rd shift: 16176

Cost per kWHr

Enter the cost per kWHr for each shift.

The scale factor multiplied by the

monetary units to determine the

energy cost.

Monetary Scale Factor

16177

Values: -3 to 3

Default: 0

Power Analysis Values

The power meter provides a number of power analysis values that can be used to detect

power quality problems, diagnose wiring problems, and more. Table 4–6 on page 38

summarizes the power analysis values.

•

THD. Total Harmonic Distortion (THD) is a quick measure of the total distortion present

in a waveform and is the ratio of harmonic content to the fundamental. It provides a

general indication of the “quality” of a waveform. THD is calculated for both voltage and

current. The power meter uses the following equation to calculate THD, where H is the

harmonic distortion:

THD =

100%

•

thd. An alternate method for calculating Total Harmonic Distortion, used widely in

Europe. It considers the total harmonic current and the total rms content rather than

fundamental content in the calculation. The power meter calculates thd for both voltage

and current. The power meter uses the following equation to calculate THD, where H is

the harmonic distortion:

100%

thd =

Total rms

•

Displacement Power Factor. Power factor (PF) represents the degree to which

voltage and current coming into a load are out of phase. Displacement power factor is

based on the angle between the fundamental components of current and voltage.

Harmonic Values. Harmonics can reduce the capacity of the power system. The power

meter determines the individual per-phase harmonic magnitudes and angles for all

currents and voltages through the:

— 31st harmonic (PM810 with PM810Log, and PM820) or

— 63rd harmonic (PM850, PM870)

The harmonic magnitudes can be formatted as either a percentage of the fundamental

(default), a percentage of the rms value, or the actual rms value. Refer to “Operation

with PQ Advanced Enabled” on page 99 for information on how to configure harmonic

calculations.

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Table 4–6: Power Analysis Values

Value

Reportable Range

THD—Voltage, Current

3-phase, per-phase, neutral

thd—Voltage, Current

0 to 3,276.7%

3-phase, per-phase, neutral

Fundamental Voltages (per phase)

Magnitude

0 to 3,276.7%

0 to 1,200 kV

0.0 to 359.9°

Angle

Fundamental Currents (per phase)

Magnitude

0 to 32,767 A

0.0 to 359.9°

Angle

Miscellaneous

Displacement P.F. (per phase, 3-phase)

Phase Rotation

–0.002 to 1.000 to +0.002

ABC or CBA

Unbalance (current and voltage) ➀

Individual Current and Voltage Harmonic Magnitudes ➁

Individual Current and Voltage Harmonic Angles ➁

➀ Readings are obtained only through communications.

0.0 to 100.0%

0 to 327.67%

0.0° to 359.9°

➁ Current and Voltage Harmonic Magnitude and Angles 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, and 13 are shown on the

display.

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Chapter 5—Input/Output Capabilities

Digital Inputs

The power meter includes one solid-state digital input. A digital input is used to detect

digital signals. For example, the digital input can be used to determine circuit breaker

status, count pulses, or count motor starts. The digital input can also be associated with an

external relay. You can log digital input transitions as events in the power meter’s on-board

alarm log. The event is date and time stamped with resolution to the second. The power

meter counts OFF-to-ON transitions for each input. You can view the count for each input

using the Digital Inputs screen, and you can reset this value using the command interface.

Figure 5–1 is an example of the Digital Inputs screen.

Figure 5–1: Digital Inputs Screen

A. Lit bargraph indicates that the input is

ON. For analog inputs or outputs, the

bargraph indicates the output



percentage.

B. SI is common to all meters and



represents standard digital input.







C. A-S1 and A-S2 represent I/O point

numbers on the first (A) module.

D. Use the arrow buttons to scroll through







the remaining I/O points. Point numbers

beginning with “B” are on the second

module.



^{}C





^D^{   }





The digital input has three operating modes:

•

Normal—Use the normal mode for simple on/off digital inputs. In normal mode, digital

inputs can be used to count KY pulses for demand and energy calculation.

•

Demand Interval Synch Pulse—you can configure any digital input to accept a

demand synch pulse from a utility demand meter (see “Demand Synch Pulse Input” on

page 40 of this chapter for more about this topic). For each demand profile, you can

designate only one input as a demand synch input.

•

Conditional Energy Control—you can configure one digital input to control conditional

energy (see “Reactive energy accumulates in four quadrants” on page 36 in Chapter

4—Metering Capabilities for more about conditional energy).

NOTE: By default, the digital input is named DIG IN S02 and is set up for normal mode.

For custom setup, use PowerLogic software to define the name and operating mode of the

digital input. The name is a 16-character label that identifies the digital input. The operating

mode is one of those listed above.

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Demand Synch Pulse Input

You can configure the power meter to accept a demand synch pulse from an external

source, such as another demand meter. By accepting demand synch pulses through a

digital input, the power meter can make its demand interval “window” match the other

meter’s demand interval “window.” The power meter does this by “watching” the digital

input for a pulse from the other demand meter. When it sees a pulse, it starts a new

demand interval and calculates the demand for the preceding interval. The power meter

then uses the same time interval as the other meter for each demand calculation. Figure

5–2 illustrates this option. See “Demand Readings” on page 30 in Chapter 4—Metering

Capabilities for more about demand calculations.

When in demand synch pulse operating mode, the power meter will not start or stop a

demand interval without a pulse. The maximum allowable time between pulses is 60

minutes. If 66 minutes (110% of the demand interval) pass before a synch pulse is

received, the power meter throws out the demand calculations and begins a new

calculation when the next pulse is received. Once in synch with the billing meter, the power

meter can be used to verify peak demand charges.

Important facts about the power meter’s demand synch feature are listed below:

•

Any installed digital input can be set to accept a demand synch pulse.

Each system can choose whether to use an external synch pulse, but only one demand

synch pulse can be brought into the meter for each demand system. One input can be

used to synchronize any combination of the demand systems.

•

The demand synch feature can be set up using PowerLogic software.

Figure 5–2: Demand synch pulse timing

Normal Demand Mode

External Synch Pulse Demand Timing

Billing Meter

Demand Timing

Utility Meter

Synch Pulse

Power Meter

Demand Timing

(Slave to Master)

Power Meter

Demand Timing

Relay Output Operating Modes

The relay output defaults to external control, but you can choose whether the relay is set to

external or internal control:

•

External (remote) control—the relay is controlled either from a PC using PowerLogic

software or a programmable logic controller using commands via communications.

•

Power meter alarm (internal) control—the relay is controlled by the power meter in

response to a set-point controlled alarm condition, or as a pulse initiator output. Once

you’ve set up a relay for power meter control, you can no longer operate the relay

remotely. However, you can temporarily override the relay, using PowerLogic software.

NOTE: If any basic setup parameters or I/O setup parameters are modified, all relay

outputs will be de-energized.

The 11 relay operating modes are as follows:

•

Normal

— Externally Controlled: Energize the relay by issuing a command from a remote PC

or programmable controller. The relay remains energized until a command to de-

energize is issued from the remote PC or programmable controller, or until the

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PowerLogic^TMSeries 800 Power Meter

Chapter 5—Input/Output Capabilities

power meter loses control power. When control power is restored, the relay is not

automatically re-energized.

— Power Meter Alarm: When an alarm condition assigned to the relay occurs, the

relay is energized. The relay is not de-energized until all alarm conditions assigned

to the relay have dropped out, the power meter loses control power, or the alarms

are over-ridden using PowerLogic software. If the alarm condition is still true when

the power meter regains control power, the relay will be re-energized.

•

Latched

— Remotely Controlled: Energize the relay by issuing a command from a remote PC

or programmable controller. The relay remains energized until a command to de-

energize is issued from a remote PC or programmable controller, or until the power

meter loses control power. When control power is restored, the relay will not be re-

energized.

— Power Meter Controlled: When an alarm condition assigned to the relay occurs,

the relay is energized. The relay remains energized—even after all alarm conditions

assigned to the relay have dropped out—until a command to de-energize is issued

from a remote PC or programmable controller, until the high priority alarm log is

cleared from the display, or until the power meter loses control power. When control

power is restored, the relay will not be re-energized if the alarm condition is not

TRUE.

•

Timed

— Remotely Controlled: Energize the relay by issuing a command from a remote PC

or programmable controller. The relay remains energized until the timer expires, or

until the power meter loses control power. If a new command to energize the relay is

issued before the timer expires, the timer restarts. If the power meter loses control

power, the relay will not be re-energized when control power is restored and the

timer will reset to zero.

— Power Meter Controlled: When an alarm condition assigned to the relay occurs, the

relay is energized. The relay remains energized for the duration of the timer. When

the timer expires, the relay will de-energize and remain de-energized. If the relay is

on and the power meter loses control power, the relay will not be re-energized when

control power is restored and the timer will reset to zero.

•

End Of Power Demand Interval

This mode assigns the relay to operate as a synch pulse to another device. The output

operates in timed mode using the timer setting and turns on at the end of a power

demand interval. It turns off when the timer expires.

Absolute kWh Pulse

This mode assigns the relay to operate as a pulse initiator with a user-defined number

of kWh per pulse. In this mode, both forward and reverse real energy are treated as

additive (as in a tie circuit breaker).

Absolute kVARh Pulse

This mode assigns the relay to operate as a pulse initiator with a user-defined number

of kVARh per pulse. In this mode, both forward and reverse reactive energy are treated

as additive (as in a tie circuit breaker).

•

kVAh Pulse

This mode assigns the relay to operate as a pulse initiator with a user-defined number

of kVAh per pulse. Since kVA has no sign, the kVAh pulse has only one mode.

kWh In Pulse

This mode assigns the relay to operate as a pulse initiator with a user-defined number

of kWh per pulse. In this mode, only the kWh flowing into the load is considered.

kVARh In Pulse

This mode assigns the relay to operate as a pulse initiator with a user-defined number

of kVARh per pulse. In this mode, only the kVARh flowing into the load is considered.

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•

kWh Out Pulse

This mode assigns the relay to operate as a pulse initiator with a user-defined number

of kWh per pulse. In this mode, only the kWh flowing out of the load is considered.

kVARh Out Pulse

This mode assigns the relay to operate as a pulse initiator with a user-defined number

of kVARh per pulse. In this mode, only the kVARh flowing out of the load is considered.

The last seven modes in the list above are for pulse initiator applications. All Series 800

Power Meters are equipped with one solid-state KY pulse output rated at 100 mA. The

solid-state KY output provides the long life—billions of operations—required for pulse

initiator applications.

The KY output is factory configured with Name = KY, Mode = Normal, and Control =

External. To set up custom values, press SETUP > I/O. For detailed instructions, see “I/O

(Input/Output) Setup” on page 18. Then using PowerLogic software, you must define the

following values for each mechanical relay output:

•

Name—A 16-character label used to identify the digital output.

Mode—Select one of the operating modes listed above.

Pulse Weight—You must set the pulse weight, the multiplier of the unit being

measured, if you select any of the pulse modes (last 7 listed above).

•

Timer—You must set the timer if you select the timed mode or end of power demand

interval mode (in seconds).

Control—You must set the relay to be controlled either remotely or internally (from the

power meter) if you select the normal, latched, or timed mode.

For instructions on setting up digital I/Os using software, see your software documentation

or help file.

Solid-state KY Pulse Output

This section describes the pulse output capabilities of the power meter. For instructions on

wiring the KY pulse output, see “Wiring the Solid-State KY Output” in the installation guide.

The power meter’s digital output is generated by a solid-state device that can be used as a

KY pulse output. This solid-state relay provides the extremely long life—billions of

operations—required for pulse initiator applications.

The KY output is a Form-A contact with a maximum rating of 100 mA. Because most pulse

initiator applications feed solid-state receivers with low burdens, this 100 mA rating is

adequate for most applications.

When setting the kWh/pulse value, set the value based on a 2-wire pulse output. For

instructions on calculating the correct value, see “Calculating the Kilowatthour-Per-Pulse

Value” on page 43 in this chapter.

The KY pulse output can be configured to operate in one of 11 operating modes. See

“Relay Output Operating Modes” on page 40 for a description of the modes.

2-wire Pulse Initiator

Figure 5–3 shows a pulse train from a 2-wire pulse initiator application.

Figure 5–3: Two-wire pulse train

ΔT

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Chapter 5—Input/Output Capabilities

In Figure 5–3, the transitions are marked as 1 and 2. Each transition represents the time

when the relay contact closes. Each time the relay transitions, the receiver counts a pulse.

The power meter can deliver up to 12 pulses per second in a 2-wire application.

Fixed Pulse Output

Fixed pulse output mode generates a fixed duration pulse output that can be associated

with kWh consumption. Figure 5–4 shows the difference in pulse duration values when

either TRANS mode or PULSE mode is selected. This mode selection is configured on the

MAINT > IO > ADVAN menu.

Figure 5–4: Fixed-pulse output

TRANS & PULSE mode

Pulse Weight = 0.02kWHr/pulse

TRANS mode:

Counts = 4

Setting in ADV mode:

10, 25, 50, 100, 150,

200, 300, 500, 1000

100 msec

PULSE mode (100ms):

Counts = 8

0.02kW

0.04kW

0.06kW

0.08kW

0.1kW

0.12kW

0.14kW

0.16kW

Calculating the Kilowatthour-Per-Pulse Value

The following example illustrates how to calculate kilowatthours per pulse (pulse weight).

To calculate this value, first determine the highest kW value you can expect and the

required pulse rate. Remember the maximum number of pulses is 8 per second.

In this example, the following conditions are set:

•

The metered load should not exceed 1600 kW.

About two KY pulses per second should normally occur. (If a higher load is reached, the

number of pulses per second can increase and still stay within the set limits.)

Step 1: Convert 1600 kW load into kWh/second.

(1600 kW)(1 Hr) = 1600 kWh

(1600 kWh)

1 hour

X kWh

1 second

------------------------------ = -----------------------

(1600 kWh)

3600 seconds

X kWh

1 second

------------------------------------ = -----------------------

X = 1600/3600 = 0.444 kWh/second

Step 2: Calculate the kWh required per pulse.

0.444 kWh/second

------------------------------------------------- = 0 . 2 2 2 kW h / p u l s e

2 pulses/second

Step 3: Adjust for the KY initiator (KY will give one pulse per two transitions of the relay).

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0.222 kWh/second

------------------------------------------------- = 0 . 1 1 1 1 kW h / p u ls e

Step 4: Round to nearest hundredth, since the power meter only accepts 0.01 kWh

increments.

Pulse Weight (Ke) = 0.11 kWh/pulse

Analog Inputs

With a PM8M2222 option module installed, a power meter can accept either voltage or

current signals through the analog inputs on the option module. The power meter stores a

minimum and a maximum value for each analog input.

For technical specifications and instructions on installing and configuring the analog inputs

on the PM8M2222, refer to the instruction bulletin (63230-502-200) that ships with the

option module. To set up an analog input, you must first set it up from the display. From the

SUMMARY screen, select MAINT > SETUP > I/O, then select the appropriate analog input

option. Then, in PowerLogic software, define the following values for each analog input:

•

Name—a 16-character label used to identify the analog input.

Units—the units of the monitored analog value (for example, “psi”).

Scale factor—multiplies the units by this value (such as tenths or hundredths).

Report Range Lower Limit—the value the Power Meter reports when the input

reaches a minimum value. When the input current is below the lowest valid reading, the

Power Meter reports the lower limit.

•

Report Range Upper Limit—the value the power meter reports when the input

reaches the maximum value. When the input current is above highest valid reading, the

Power Meter reports the upper limit.

For instructions on setting up analog inputs using software, see your software

documentation or Help file.

Analog Outputs

This section describes the analog output capabilities when a PM8M2222 is installed on the

Power Meter. For technical specifications and instructions on installing and configuring the

analog outputs on the PM8M2222, refer to the instruction bulletin (63230-502-200) that

ships with the option module.

To set up an analog output, you must first set it up from the display. From the SUMMARY

screen, select MAINT > SETUP > I/O, then select the appropriate analog output option.

Then, in PowerLogic software, define the following values for each analog input

•

Name—a 16-character label used to identify the output. Default names are assigned,

but can be customized

•

Output register—the Power Meter register assigned to the analog output.

Lower Limit—the value equivalent to the minimum output current. When the register

value is below the lower limit, the Power Meter outputs the minimum output current.

•

Upper Limit—the value equivalent to the maximum output current. When the register

value is above the upper limit, the Power Meter outputs the maximum output current.

For instructions on setting up an analog output using software, see your software

documentation or Help file.

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PowerLogic^TMSeries 800 Power Meter

Chapter 6—Alarms

This section describes the alarm features on all Series 800 Power Meters. For information

about advanced alarm features, go to “Advanced Alarms” on page 53.

Basic Alarms

The power meter can detect over 50 alarm conditions, including over or under conditions,

digital input changes, phase unbalance conditions, and more. It also maintains a counter

for each alarm to keep track of the total number of occurrences. A complete list of default

basic alarm configurations are described in Table 6–5 on page 51 . In addition, you can set

up your own custom alarms after installing an input/output module (PM8M22, PM8M26, or

PM8M2222).

When one or more alarm conditions are true, the power meter will execute a task

automatically. When an alarm is active, the !alarm icon appears in the upper-right corner

of the power meter display. If a PM810LOG is installed on a PM810, PowerLogic software

can be used to set up each alarm condition to force data log entries in a single data log file.

For the PM820, PM850, and PM870 PowerLogic software can be used to set up each

alarm condition to force data log entries in up to three user-defined data log files. See

Chapter 7—Logging on page 57 for more about data logging.

NOTE: PM820 only supports one data log.

Table 6–1: Basic alarm features by model

PM810 with

Basic Alarm Feature

PM810

PM820

PM850

PM870

PM810LOG

Standard alarms

Open slots for additional

standard alarms

➀

➁

Digital

Custom alarms

Yes

➀ Available when an I/O module with analog IN/OUT is installed.

➁ Requires an input/output option module (PM8M22, PM8M26, or the PM8M2222).

Basic Alarm Groups

When using a default alarm, you first choose the alarm group that is appropriate for the

application. Each alarm condition is assigned to one of these alarm groups:

Whether you are using a default alarm or creating a custom alarm, you first choose the

alarm group that is appropriate for the application. Each alarm condition is assigned to one

of these alarm groups:

•

Standard—Standard alarms have a detection rate of 1 second and are useful for

detecting conditions such as over current and under voltage. Up to 40 alarms can be

set up in this alarm group.

Digital—Digital alarms are triggered by an exception such as the transition of a digital

input or the end of an incremental energy interval. Up to 12 alarms can be set up in this

group.

Custom—The power meter has many pre-defined alarms, but you can also set up your

own custom alarms using PowerLogic software. For example, you may need to alarm

on the ON-to-OFF transition of a digital input. To create this type of custom alarm:

1. Select the appropriate alarm group (digital in this case).

2. Select the type of alarm (described in Table 6–6 on page 52 ).

3. Give the alarm a name.

4. Save the custom alarm.

After creating a custom alarm, you can configure it by applying priorities, setting pickups

and dropouts (if applicable), and so forth.

Both the power meter display and PowerLogic software can be used to set up standard,

digital, and custom alarm types.

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Chapter 6—Alarms

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Setpoint-driven Alarms

Many of the alarm conditions require that you define setpoints. This includes all alarms for

over, under, and phase unbalance alarm conditions. Other alarm conditions such as digital

input transitions and phase reversals do not require setpoints. For those alarm conditions

that require setpoints, you must define the following information:

•

Pickup Setpoint

Pickup Delay

Dropout Setpoint

Dropout Delay

NOTE: Alarms with both Pickup and Dropout setpoints set to zero are invalid.

The following two figures will help you understand how the power meter handles setpoint-

driven alarms. Figure 6–1 shows what the actual alarm Log entries for Figure 6–2 might

look like, as displayed by PowerLogic software.

NOTE: The software does not actually display the codes in parentheses—EV1, EV2, Max1,

Max2. These are only references to the codes in Figure 6–2.

Figure 6–1: Sample alarm log entry

(EV2)

(Max2)

(EV1)

(Max1)

Figure 6–2: How the power meter handles setpoint-driven alarms

Max2

Max1

Pickup

Setpoint

Dropout

Setpoint

Pickup Delay

Dropout Delay

EV2

EV1

Alarm Period

EV1—The power meter records the date and time that the pickup setpoint and time delay

were satisfied, and the maximum value reached (Max1) during the pickup delay period

(T). Also, the power meter performs any tasks assigned to the event such as waveform

captures or forced data log entries.

EV2—The power meter records the date and time that the dropout setpoint and time delay

were satisfied, and the maximum value reached (Max2) during the alarm period.

The power meter also stores a correlation sequence number (CSN) for each event (such as

Under Voltage Phase A Pickup, Under Voltage Phase A Dropout). The CSN lets you relate

pickups and dropouts in the alarm log. You can sort pickups and dropouts by CSN to

correlate the pickups and dropouts of a particular alarm. The pickup and dropout entries of

an alarm will have the same CSN. You can also calculate the duration of an event by

looking at pickups and dropouts with the same CSN.

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Chapter 6—Alarms

Priorities

Each alarm also has a priority level. Use the priorities to distinguish between events that

require immediate action and those that do not require action.

•

High priority—if a high priority alarm occurs, the display informs you in two ways: the

LED backlight on the display flashes until you acknowledge the alarm and the alarm

icon blinks while the alarm is active.

•

Medium priority—if a medium priority alarm occurs, the alarm icon blinks only while

the alarm is active. Once the alarm becomes inactive, the alarm icon stops blinking and

remains on the display.

•

Low priority—if a low priority alarm occurs, the alarm icon blinks only while the alarm is

active. Once the alarm becomes inactive, the alarm icon disappears from the display.

No priority—if an alarm is set up with no priority, no visible representation will appear

on the display. Alarms with no priority are not entered in the Alarm Log. See Chapter

7—Logging for alarm logging information.

If multiple alarms with different priorities are active at the same time, the display shows the

alarm message for the last alarm that occurred. For instructions on setting up alarms from

the power meter display, see “ALARM (Alarms) Setup” on page 17.

Viewing Alarm Activity and History

1. Press ###:until ALARM is visible.

2. Press ALARM.

ꢝꢬꢄꢇꢆꢬꢔꢕ

ꢌꢍꢇꢆꢉ

ꢉꢀꢁ

ꢂꢅꢆ

ꢆꢄꢇꢀꢁꢇꢆꢄ

ꢑꢆ

3. View the active alarm listed on the power

meter display. If there are no active

alarms, the screen reads, “NO ACTIVE

ALARM.”

ꢁꢊꢃꢚꢌ

ꢹ

4. If there are active alarms, press

ꢋꢫꢰꢻ

<--or -->to view a different alarm.

5. Press HIST.

ꢖ꣈ꢌꢳꢖ

6. Press <--or -->to view a different

ꢈꢉ

ꢙꢍꢍ

ꢍꢍꣅ

ꢂꢔꢚꢊꢬ

alarm’s history.

7. Press 1;to return to the SUMMARY

screen.

Types of Setpoint-controlled Functions

This section describes some common alarm functions to which the following information

applies:

•

Values that are too large to fit into the display may require scale factors. For more

information on scale factors, refer to “Changing Scale Factors” on page 91.

Relays can be configured as normal, latched, or timed. See “Relay Output Operating

Modes” on page 40 for more information.

When the alarm occurs, the power meter operates any specified relays. There are two

ways to release relays that are in latched mode:

— Issue a command to de-energize a relay. See Appendix C—Using the Command

Interface on page 83 for instructions on using the command interface, or

— Acknowledge the alarm in the high priority log to release the relays from latched

mode. From the main menu of the display, press ALARM to view and acknowledge

unacknowledged alarms.

The list that follows shows the types of alarms available for some common alarm functions:

NOTE: Voltage based alarm setpoints depend on your system configuration. Alarm

setpoints for 3-wire systems are V values while 4-wire systems are V

values.

L-L

L-N

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Chapter 6—Alarms

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Under-voltage: Pickup and dropout setpoints are entered in volts. The per-phase under-

voltage alarm occurs when the per-phase voltage is equal to or below the pickup setpoint

long enough to satisfy the specified pickup delay (in seconds). The under-voltage alarm

clears when the phase voltage remains above the dropout setpoint for the specified dropout

delay period.

Over-voltage: Pickup and dropout setpoints are entered in volts. The per-phase over-

voltage alarm occurs when the per-phase voltage is equal to or above the pickup setpoint

long enough to satisfy the specified pickup delay (in seconds). The over-voltage alarm

clears when the phase voltage remains below the dropout setpoint for the specified dropout

delay period.

Unbalance Current: Pickup and dropout setpoints are entered in tenths of percent, based

on the percentage difference between each phase current with respect to the average of all

phase currents. For example, enter an unbalance of 7% as 70. The unbalance current

alarm occurs when the phase current deviates from the average of the phase currents, by

the percentage pickup setpoint, for the specified pickup delay. The alarm clears when the

percentage difference between the phase current and the average of all phases remains

below the dropout setpoint for the specified dropout delay period.

Unbalance Voltage: Pickup and dropout setpoints are entered in tenths of percent, based

on the percentage difference between each phase voltage with respect to the average of all

phase voltages. For example, enter an unbalance of 7% as 70. The unbalance voltage

alarm occurs when the phase voltage deviates from the average of the phase voltages, by

the percentage pickup setpoint, for the specified pickup delay. The alarm clears when the

percentage difference between the phase voltage and the average of all phases remains

below the dropout setpoint for the specified dropout delay (in seconds).

Phase Loss—Current: Pickup and dropout setpoints are entered in amperes. The phase

loss current alarm occurs when any current value (but not all current values) is equal to or

below the pickup setpoint for the specified pickup delay (in seconds). The alarm clears

when one of the following is true:

•

All of the phases remain above the dropout setpoint for the specified dropout delay, or

All of the phases drop below the phase loss pickup setpoint.

If all of the phase currents are equal to or below the pickup setpoint, during the pickup

delay, the phase loss alarm will not activate. This is considered an under current condition.

It should be handled by configuring the under current alarm functions.

Phase Loss—Voltage: Pickup and dropout setpoints are entered in volts. The phase loss

voltage alarm occurs when any voltage value (but not all voltage values) is equal to or

below the pickup setpoint for the specified pickup delay (in seconds). The alarm clears

when one of the following is true:

•

All of the phases remain above the dropout setpoint for the specified dropout delay (in

seconds), OR

All of the phases drop below the phase loss pickup setpoint.

If all of the phase voltages are equal to or below the pickup setpoint, during the pickup

delay, the phase loss alarm will not activate. This is considered an under voltage condition.

It should be handled by configuring the under voltage alarm functions.

Reverse Power: Pickup and dropout setpoints are entered in kilowatts or kVARs. The

reverse power alarm occurs when the power flows in a negative direction and remains at or

below the negative pickup value for the specified pickup delay (in seconds). The alarm

clears when the power reading remains above the dropout setpoint for the specified

dropout delay (in seconds).

Phase Reversal: Pickup and dropout setpoints do not apply to phase reversal. The phase

reversal alarm occurs when the phase voltage rotation differs from the default phase

rotation. The power meter assumes that an ABC phase rotation is normal. If a CBA phase

rotation is normal, the user must change the power meter’s phase rotation from ABC

(default) to CBA. To change the phase rotation from the display, from the main menu select

Setup > Meter > Advanced. For more information about changing the phase rotation setting

of the power meter, refer to “ADVAN (Advanced) Power Meter Setup Features” on

page 19.

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Chapter 6—Alarms

Scale Factors

A scale factor is the multiplier expressed as a power of 10. For example, a multiplier of 10 is

represented as a scale factor of 1, since 10 =10; a multiplier of 100 is represented as a

scale factor of 2, since 10 =100. This allows you to make larger values fit into the register.

Normally, you do not need to change scale factors. If you are creating custom alarms, you

need to understand how scale factors work so that you do not overflow the register with a

number larger than what the register can hold. When PowerLogic software is used to set up

alarms, it automatically handles the scaling of pickup and dropout setpoints. When creating

a custom alarm using the power meter’s display, do the following:

•

Determine how the corresponding metering value is scaled, and

Take the scale factor into account when entering alarm pickup and dropout settings.

Pickup and dropout settings must be integer values in the range of -32,767 to +32,767. For

example, to set up an under voltage alarm for a 138 kV nominal system, decide upon a

setpoint value and then convert it into an integer between -32,767 and +32,767. If the under

voltage setpoint were 125,000 V, this would typically be converted to 12500 x 10 and

entered as a setpoint of 12500.

Six scale groups are defined (A through F). The scale factor is preset for all factory-

configured alarms. Table 6–2 lists the available scale factors for each of the scale groups.

If you need either an extended range or more resolution, select any of the available scale

factors to suit your need. Refer to “Changing Scale Factors” on page 91 of

Appendix C—Using the Command Interface.

Table 6–2: Scale Groups

Scale Group

Measurement Range

Scale Factor

Amperes

0–327.67 A

–2

Scale Group A—Phase Current

0–3,276.7 A

–1

0–32,767 A

0 (default)

0–327.67 kA

Amperes

0–327.67 A

–2

Scale Group B—Neutral Current

0–3,276.7 A

–1

0–32,767 A

0 (default)

0–327.67 kA

Voltage

0–3,276.7 V

–1

Scale Group D—Voltage

0–32,767 V

0 (default)

0–327.67 kV

0–3,276.7 kV

Power

0–32.767 kW, kVAR, kVA

0–327.67 kW, kVAR, kVA

0–3,276.7 kW, kVAR, kVA

0–32,767 kW, kVAR, kVA

0–327.67 MW, MVAR, MVA

0–3,276.7 MW, MVAR, MVA

0–32,767 MW, MVAR, MVA

–3

–2

–1

Scale Group F—Power kW, kVAR, kVA

0 (default)

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Chapter 6—Alarms

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Scaling Alarm Setpoints

This section is for users who do not have PowerLogic software and need to set up alarms

from the power meter display. It explains how to scale alarm setpoints.

When the power meter is equipped with a display, most metered quantities are limited to

five characters (plus a positive or negative sign). The display will also show the engineering

units applied to that quantity.

To determine the proper scaling of an alarm setpoint, view the register number for the

associated scale group. The scale factor is the number in the Dec column for that register.

For example, the register number for Scale D to Phase Volts is 3212. If the number in the

Dec column is 1, the scale factor is 10 (10 =10). Remember that scale factor 1 in

Table 6–3 on page 50 for Scale Group D is measured in kV. Therefore, to define an alarm

setpoint of 125 kV, enter 12.5 because 12.5 multiplied by 10 is 125. Below is a table listing

the scale groups and their register numbers.

Table 6–3: Scale Group Register Numbers

Scale Group

Scale Group A—Phase Current

3209

3210

3211

3212

3214

Scale Group B—Neutral Current

Scale Group C—Ground Current

Scale Group D—Voltage

Scale Group F—Power kW, kVAR, kVA

Alarm Conditions and Alarm Numbers

This section lists the power meter’s predefined alarm conditions. For each alarm condition,

the following information is provided.

•

Alarm No.—a position number indicating where an alarm falls in the list.

Alarm Description—a brief description of the alarm condition

Abbreviated Display Name—an abbreviated name that describes the alarm condition

but is limited to 15 characters that fit in the window of the power meter’s display.

•

Test Register—the register number that contains the value (where applicable) that is

used as the basis for a comparison to alarm pickup and dropout settings.

•

Units—the unit that applies to the pickup and dropout settings.

Scale Group—the scale group that applies to the test register’s metering value (A–F).

For a description of scale groups, see “Scale Factors” on page 49.

•

Alarm Type—a reference to a definition that provides details on the operation and

configuration of the alarm. For a description of alarm types, refer to Table 6–6 on page

52 .

Table 6– 4 lists the default alarm configuration - factory-enabled alarms.

Table 6– 5 lists the default basic alarms by alarm number.

Table 6– 6 lists the alarm types.

Table 6–4: Default Alarm Configuration - Factory-enabled Alarms

Pickup

Dropout

Limit Time

Delay

Alarm

No.

Pickup

Limit

Dropout

Limit

Standard Alarm

Limit Time

Delay

Voltage Unbalance L-N

20 (2.0%)

300

20 (2.0%)

300

Max. Voltage Unbalance L-L

End of Incremental Energy Interval

Power-up Reset

20 (2.0%)

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Chapter 6—Alarms

Table 6–5: List of Default Basic Alarms by Alarm Number

Alarm

Number

Abbreviated

Display Name Register

Test

Scale Alarm

Group Type

Alarm Description

Units

➀

➁

Standard Speed Alarms (1 Second)

Over Current Phase A

Over Current Phase B

Over Current Phase C

Over Current Neutral

Over Ia

1100

1101

1102

1103

1110

3262

1124

1125

1126

1120

1121

1122

1124

1125

1126

1120

1121

1122

1136

1132

Amperes

Tenths %

Amperes

Volts

010

053

010

020

010

Over Ib

Over Ic

Over In

Current Unbalance, Max

Current Loss

I Unbal Max

Current Loss

Over Van

—

Over Voltage Phase A–N

Over Voltage Phase B–N

Over Voltage Phase C–N

Over Voltage Phase A–B

Over Voltage Phase B–C

Over Voltage Phase C–A

Under Voltage Phase A

Under Voltage Phase B

Under Voltage Phase C

Under Voltage Phase A–B

Under Voltage Phase B–C

Under Voltage Phase C–A

Voltage Unbalance L–N, Max

Voltage Unbalance L–L, Max

—

Over Vbn

Volts

Over Vcn

Volts

Over Vab

Over Vbc

Volts

Over Vca

Volts

Under Van

Under Vbn

Under Vcn

Under Vab

Under Vbc

Under Vca

V Unbal L-N Max

V Unbal L-L Max

Volts

Tenths %

Voltage Loss (loss of A,B,C, but

not all)

Voltage Loss

3262

Volts

052

Phase Reversal

Phase Rev

3228

2151

1163

1207

1208

1209

1211

1212

1213

2181

1143

1151

—

051

011

055

010

011

Over kW Demand

Over kW Dmd

Lag True PF

Lagging true power factor

Thousandths

Tenths %

kVA

—

Over THD of Voltage Phase A–N Over THD Van

Over THD of Voltage Phase B–N Over THD Vbn

Over THD of Voltage Phase C–N Over THD Vcn

Over THD of Voltage Phase A–B Over THD Vab

Over THD of Voltage Phase B–C Over THD Vbc

Over THD of Voltage Phase C–A Over THD Vca

Over kVA Demand

Over kW Total

Over kVA Dmd

Over kW Total

Over kVA Total

kVA

Reserved for additional analog

alarms ➂

34-40

—

Reserved for custom alarms.

Digital

End of incremental energy

interval

End Inc Enr Int

N/A

—

070

End of power demand interval

Power up/Reset

End Dmd Int

Pwr Up/Reset

DIG IN S02

N/A

—

070

060

Digital Input OFF/ON

Reserved for additional digital

alarms ➂

05-12

—

Reserved for custom alarms

➀ Scale groups are described in Table 6–2 on page 49 .

➁ Alarm types are described in Table 6–6 on page 52 .

➂ Additional analog and digital alarms require a corresponding I/O module to be installed.

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Chapter 6—Alarms

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Table 6–6: Alarm Types

Type Description

Operation

Standard Speed

If the test register value exceeds the setpoint long enough to satisfy the pickup

delay period, the alarm condition will be true. When the value in the test register

falls below the dropout setpoint long enough to satisfy the dropout delay period,

the alarm will drop out. Pickup and dropout setpoints are positive, delays are in

seconds.

010 Over Value Alarm

If the absolute value in the test register exceeds the setpoint long enough to

satisfy the pickup delay period, the alarm condition will be true. When absolute the

value in the test register falls below the dropout setpoint long enough to satisfy the

dropout delay period, the alarm will drop out. Pickup and dropout setpoints are

positive, delays are in seconds.

011 Over Power Alarm

If the absolute value in the test register exceeds the setpoint long enough to

satisfy the pickup delay period, the alarm condition will be true. When absolute the

value in the test register falls below the dropout setpoint long enough to satisfy the

dropout delay period, the alarm will drop out. This alarm will only hold true for

reverse power conditions. Positive power values will not cause the alarm to occur.

Pickup and dropout setpoints are positive, delays are in seconds.

Over Reverse

012

Power Alarm

If the test register value is below the setpoint long enough to satisfy the pickup

delay period, the alarm condition will be true. When the value in the test register

rises above the dropout setpoint long enough to satisfy the dropout delay period,

the alarm will drop out. Pickup and dropout setpoints are positive, delays are in

seconds.

020 Under Value Alarm

021 Under Power Alarm

051 Phase Reversal

If the absolute value in the test register is below the setpoint long enough to

satisfy the pickup delay period, the alarm condition will be true. When the absolute

value in the test register rises above the dropout setpoint long enough to satisfy

the dropout delay period, the alarm will drop out. Pickup and dropout setpoints are

positive, delays are in seconds.

The phase reversal alarm will occur whenever the phase voltage waveform

rotation differs from the default phase rotation. The ABC phase rotation is

assumed to be normal. If a CBA phase rotation is normal, the user should

reprogram the power meter’s phase rotation ABC to CBA phase rotation. The

pickup and dropout setpoints for phase reversal do not apply.

The phase loss voltage alarm will occur when any one or two phase voltages (but

not all) fall to the pickup value and remain at or below the pickup value long

enough to satisfy the specified pickup delay. When all of the phases remain at or

above the dropout value for the dropout delay period, or when all of the phases

drop below the specified phase loss pickup value, the alarm will drop out. Pickup

and dropout setpoints are positive, delays are in seconds.

052 Phase Loss, Voltage

053 Phase Loss, Current

The phase loss current alarm will occur when any one or two phase currents (but

not all) fall to the pickup value and remain at or below the pickup value long

enough to satisfy the specified pickup delay. When all of the phases remain at or

above the dropout value for the dropout delay period, or when all of the phases

drop below the specified phase loss pickup value, the alarm will drop out. Pickup

and dropout setpoints are positive, delays are in seconds.

The leading power factor alarm will occur when the test register value becomes

more leading than the pickup setpoint (such as closer to 0.010) and remains more

leading long enough to satisfy the pickup delay period. When the value becomes

equal to or less leading than the dropout setpoint, that is 1.000, and remains less

054 Leading Power Factor leading for the dropout delay period, the alarm will drop out. Both the pickup

setpoint and the dropout setpoint must be positive values representing leading

power factor. Enter setpoints as integer values representing power factor in

thousandths. For example, to define a dropout setpoint of 0.5, enter 500. Delays

are in seconds.

The lagging power factor alarm will occur when the test register value becomes

more lagging than the pickup setpoint (such as closer to –0.010) and remains

more lagging long enough to satisfy the pickup delay period. When the value

becomes equal to or less lagging than the dropout setpoint and remains less

055 Lagging Power Factor lagging for the dropout delay period, the alarm will drop out. Both the pickup

setpoint and the dropout setpoint must be positive values representing lagging

power factor. Enter setpoints as integer values representing power factor in

thousandths. For example, to define a dropout setpoint of –0.5, enter 500. Delays

are in seconds.

Digital

The digital input transition alarms will occur whenever the digital input changes

from off to on. The alarm will dropout when the digital input changes back to on

from off. The pickup and dropout setpoints and delays do not apply.

060 Digital Input On

061 Digital Input Off

070 Unary

The digital input transition alarms will occur whenever the digital input changes

from on to off.The alarm will dropout when the digital input changes back to off

from on. The pickup and dropout setpoints and delays do not apply.

This is a internal signal from the power meter and can be used, for example, to

alarm at the end of an interval or when the power meter is reset. Neither the

pickup and dropout delays nor the setpoints apply.

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PowerLogic^TMSeries 800 Power Meter

Chapter 6—Alarms

Advanced Alarms

This section describes the advanced alarm features found on the PM850 and the PM870.

For information about basic alarm features, see “Basic Alarms” on page 45.

Table 6 – 7: Advanced alarm features by model

Advanced Alarm Feature

PM850

PM870

Boolean alarms

Disturbance alarms

Alarm levels

—

Yes

Custom alarms

Advanced Alarm Groups

In addition to the basic alarm groups (see “Basic Alarm Groups” on page 45), the

following advanced alarm groups are available.

•

Boolean—Boolean alarms use Boolean logic to combine up to four enabled alarms.

You can choose from the Boolean logic operands: AND, NAND, OR, NOR, or XOR to

combine your alarms. Up to 10 alarms can be set up in this group.

Disturbance (PM870)—Disturbance alarms have a detection rate of half a cycle and

are useful for detecting voltage sags and swells. The Power Meter comes configured

with 12 default voltage sag and swell alarms; current sag and swell alarms are available

by configuring custom alarms. Up to 12 disturbance alarms can be set up in this group.

For more information about disturbance monitoring, see Chapter 9—Disturbance

Monitoring (PM870) on page 65.

•

Custom—The power meter has many pre-defined alarms, but you can also set up your

own custom alarms using PowerLogic software. For example, you may need to alarm

on a sag condition for current A. To create this type of custom alarm:

1. Select the appropriate alarm group (Disturbance in this case).

2. Delete any of the default alarms you are not using from the disturbance alarms

group (for example, Sag Vbc). The Add button should be available now.

3. Click Add, then select Disturbance, Sag, and Current A.

4. Give the alarm a name.

5. Save the custom alarm.

After creating a custom alarm, you can configure it by applying priorities, setting pickups

and dropouts (if applicable), and so forth.

PowerLogic software can be used to configure any of the advanced alarm types, but the

power meter display cannot be used. Also, use PowerLogic software to delete an alarm

and create a new alarm for evaluating other metered quantities.

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Chapter 6—Alarms

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Alarm Levels

Using PowerLogic software with a PM850 or PM870, multiple alarms can be set up for one

particular quantity (parameter) to create alarm “levels”. You can take different actions

depending on the severity of the alarm.

For example, you could set up two alarms for kW Demand. A default alarm already exists

for kW Demand, but you could create another custom alarm for kW Demand, selecting

different pickup points for it. The custom kW Demand alarm, once created, will appear in

the standard alarm list. For illustration purposes, let’s set the default kW Demand alarm to

120 kW and the new custom alarm to 150 kW. One alarm named kW Demand ; the other

kW Demand 150kW as shown in Figure 6–3. If you choose to set up two alarms for the

same quantity, use slightly different names to distinguish which alarm is active. The display

can hold up to 15 characters for each name. You can create up to 10 alarm levels for each

quantity.

Figure 6–3:Two alarms set up for the same quantity with different pickup and dropout set

points

kW Demand

Alarm #43 Pick Up

150

140

130

120

100

Alarm #43 Drop Out

Alarm #26 Pick Up

Alarm #26 Drop Out

Time

Demand OK Approaching

Peak Demand

Below Peak Demand OK

Demand

Peak Demand Exceeded

kW Demand (default)

Alarm #26 kW Demand with pickup

of 120 kWd, medium priority

kW Demand 150 kW (custom)

Alarm #43 kW Demand with pickup

of 150 kWd, high priority

Viewing Alarm Activity and History

1. Press ###:until ALARM is visible.

2. Press ALARM.

ꢝꢬꢄꢇꢆꢬꢔꢕ

ꢌꢍꢇꢆꢉ

ꢉꢀꢁ

ꢂꢅꢆ

ꢆꢄꢇꢀꢁꢇꢆꢄ

ꢑꢆ

3. View the active alarm listed on the power

meter display. If there are no active

alarms, the screen reads, “NO ACTIVE

ALARMS.”

ꢁꢊꢃꢚꢌ

ꢹ

4. If there are active alarms, press <--or --

ꢋꢫꢰꢻ

>to view a different alarm.

5. Press HIST.

ꢖ꣈ꢌꢳꢖ

6. Press <--or -->to view a different

ꢈꢉ

ꢙꢍꢍ

ꢍꢍꣅ

ꢂꢔꢚꢊꢬ

alarm’s history.

7. Press 1;to return to the SUMMARY

screen.

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Chapter 6—Alarms

Alarm Conditions and Alarm Numbers

This section lists the power meter’s predefined alarm conditions. For each alarm condition,

the following information is provided.

•

Alarm No.—a position number indicating where an alarm falls in the list.

Alarm Description—a brief description of the alarm condition

Abbreviated Display Name—an abbreviated name that describes the alarm condition,

but is limited to 15 characters that fit in the window of the power meter’s display.

•

Test Register—the register number that contains the value (where applicable) that is

used as the basis for a comparison to alarm pickup and dropout settings.

•

Units—the unit that applies to the pickup and dropout settings.

Scale Group—the scale group that applies to the test register’s metering value (A–F).

For a description of scale groups, see “Scale Factors” on page 49.

•

Alarm Type—a reference to a definition that provides details on the operation and

configuration of the alarm. For a description of advanced alarm types, refer to

Table 6–9.

Table 6–8 lists the preconfigured alarms by alarm number.

Table 6–8: List of Default Disturbance Alarms by Alarm Number

Alarm

Number

Abbreviated

Display Name Register

Test

Scale Alarm

Alarm Description

Units

➀

➁

Group

Type

Disturbance Monitoring (1/2 Cycle) (PM870)

Voltage Swell A

Voltage Swell B

Voltage Swell C

Voltage Swell A–B

Voltage Swell B–C

Voltage Swell C–A

Voltage Sag A–N

Voltage Sag B–N

Voltage Sag C–N

Voltage Sag A–B

Voltage Sag B–C

Voltage Sag C–A

Swell Van

Swell Vbn

Swell Vcn

Swell Vab

Swell Vbc

Swell Vca

Sag Van

Sag Vbn

Sag Vcn

Sag Vab

Sag Vbc

Sag Vca

Volts

080

➀ Scale groups are described in Table 6–2 on page 49.

➁ Advanced Alarm types are described in Table 6–9 on page 56.

NOTE: Current sag and swell alarms are enabled using PowerLogic software or by setting

up custom alarms. To do this, delete any of the above default disturbance alarms, and then

create a new current sag or swell alarm (see the example under the “Advanced Alarm

Groups” on page 53.). Sag and swell alarms are available for all channels.

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Chapter 6—Alarms

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Table 6–9: Advanced Alarm Types

Type

Description

Operation

Boolean

Logic

AND

The AND alarm will occur when all of the combined enabled alarms are

true (up to 4). The alarm will drop out when any of the enabled alarms

drops out.

100

101

102

103

104

Logic

NAND

The NAND alarm will occur when any, but not all, or none of the

combined enabled alarms are true. The alarm will drop out when all of

the enabled alarms drop out, or all are true.

Logic

The OR alarm will occur when any of the combined enabled alarms are

true (up to 4). The alarm will drop out when all of the enabled alarms

are false.

Logic

NOR

The NOR alarm will occur when none of the combined enabled alarms

are true (up to 4). The alarm will drop out when any of the enabled

alarms are true.

Logic

XOR

The XOR alarm will occur when only one of the combined enabled

alarms is true (up to 4). The alarm will drop out when the enabled alarm

drops out or when more than one alarm becomes true.

Disturbance (PM870)

The voltage swell alarms will occur whenever the continuous rms

calculation is above the pickup setpoint and remains above the pickup

setpoint for the specified number of cycles. When the continuous rms

calculations fall below the dropout setpoint and remain below the

setpoint for the specified number of cycles, the alarm will drop out.

Pickup and dropout setpoints are positive and delays are in cycles.

080

Voltage Swell

Voltage Sag

The voltage sag alarms will occur whenever the continuous rms

calculation is below the pickup setpoint and remains below the pickup

setpoint for the specified number of cycles. When the continuous rms

calculations rise above the dropout setpoint and remain above the

setpoint for the specified number of cycles, the alarm will drop out.

Pickup and dropout setpoints are positive and delays are in cycles.

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Chapter 7—Logging

Introduction

This chapter briefly describes the following logs of the power meter:

•

Alarm log

Maintenance log

Billing log

User-defined data logs

See the table below for a summary of logs supported by each power meter model.

Table 7–1: Number of Logs Supported by Model

Number of Logs per Model

Log Type

PM810 with

PM810LOG

PM810

PM820

PM850

PM870

Alarm Log

Maintenance Log

Billing Log

—

Data Log 1

Data Log 2

Data Log 3

Data Log 4

—

Logs are files stored in the non-volatile memory of the power meter and are referred to as

“on-board logs.” The amount of memory available depends on the model (see Table 7–2).

Data and billing log files are preconfigured at the factory. You can accept the preconfigured

logs or change them to meet your specific needs. Use PowerLogic software to set up and

view all the logs. See your software’s online help or documentation for information about

working with the power meter’s on-board logs.

Table 7–2: Available Memory for On-board Logs

Power Meter Model

Total Memory Available

PM810

PM810 with PM810LOG

PM820

0 KB

80 KB

800 KB

PM850

PM870

Waveform captures are stored in the power meter’s memory, but they are not considered

logs (see Chapter 8—Waveform Capture on page 63). Refer to “Memory Allocation for

Log Files”on the next page for information about memory allocation in the power meter.

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Chapter 7—Logging

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Memory Allocation for Log Files

Each file in the power meter has a maximum memory size. Memory is not shared between

the different logs, so reducing the number of values recorded in one log will not allow more

values to be stored in a different log. The following table lists the memory allocated to each

log:

Table 7–3: Memory Allocation for Each Log

Max. Records

Stored

Max. Register

Values Recorded

Storage

(Bytes)

Power Meter

Model

Log Type

Alarm Log

100

2,200

320

All models

Maintenance Log

All models

PM810 with

PM810LOGPM820

Billing Log

5000

1851

96 + 3 D/T

65,536

14,808

PM850

PM870

PM810 with

PM810LOGPM820

Data Log 1

PM850

PM870

PM850

PM870

PM850

PM870

PM850

PM870

Data Log 2

Data Log 3

Data Log 4

5000

96 + 3 D/T

393,216

32,000

Alarm Log

By default, the power meter can log the occurrence of any alarm condition. Each time an

alarm occurs it is entered into the alarm log. The alarm log in the power meter stores the

pickup and dropout points of alarms along with the date and time associated with these

alarms. You select whether the alarm log saves data as first-in-first-out (FIFO) or fill and

hold. With PowerLogic software, you can view and save the alarm log to disk, and reset the

alarm log to clear the data out of the power meter’s memory.

Alarm Log Storage

Maintenance Log

The power meter stores alarm log data in non-volatile memory. The size of the alarm log is

fixed at 100 records.

The power meter stores a maintenance log in non-volatile memory. The file has a fixed

record length of four registers and a total of 40 records. The first register is a cumulative

counter over the life of the power meter. The last three registers contain the date/time of

when the log was updated. Table 7–4 describes the values stored in the maintenance log.

These values are cumulative over the life of the power meter and cannot be reset.

NOTE: Use PowerLogic software to view the maintenance log.

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Chapter 7—Logging

Table 7–4: Values Stored in the Maintenance Log

Record

Value Stored

Number

Time stamp of the last change

Date and time of the last power failure

Date and time of the last firmware download

Date and time of the last option module change

Date and time of the latest LVC update due to configuration errors

detected during meter initialization

6–11

Reserved

Date and time the Present Month Min/Max was last reset

Date and time the Previous Month Min/Max was last reset

Date and time the Energy Pulse Output was overdriven

Date and time the Power Demand Min/Max was last reset

Date and time the Current Demand Min/Max was last reset

Date and time the Generic Demand Min/Max was last reset

Date and time the Input Demand Min/Max was last reset

Reserved

Date and time the Accumulated Energy value was last reset

Date and time the Conditional Energy value was last reset

Date and time the Incremental Energy value was last reset

Reserved

Date and time of the last Standard KY Output operation

Date and time of the last Discrete Output @A01 operation➀

Date and time of the last Discrete Output @A02 operation➀

Date and time of the last Discrete Output @A03 operation➀

Date and time of the last Discrete Output @A04 operation➀

Date and time of the last Discrete Output @A05 operation➀

Date and time of the last Discrete Output @A06 operation➀

Date and time of the last Discrete Output @A07 operation➀

Date and time of the last Discrete Output @A08 operation➀

Date and time of the last Discrete Output @B01 operation➀

Date and time of the last Discrete Output @B02 operation➀

Date and time of the last Discrete Output @B03 operation➀

Date and time of the last Discrete Output @B04 operation➀

Date and time of the last Discrete Output @B05 operation➀

Date and time of the last Discrete Output @B06 operation➀

Date and time of the last Discrete Output @B07 operation➀

Date and time of the last Discrete Output @B08 operation➀

➀ Additional outputs require option modules and are based on the I/O

configuration of that particular module.

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Chapter 7—Logging

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Data Logs

The PM810 with a PM810LOG records and stores readings at regularly scheduled intervals

in one independent data log. This log is preconfigured at the factory. You can accept the

preconfigured data log or change it to meet your specific needs. You can set up the data

log to store the following information:

The PM820 records and stores readings at regularly scheduled intervals in one

independent data log. The PM850 and PM870 record and store meter readings at regularly

scheduled intervals in up to three independent data logs. Some data log files are

preconfigured at the factory. You can accept the preconfigured data logs or change them to

meet your specific needs. You can set up each data log to store the following information:

•

Timed Interval—1 second to 24 hours for Data Log 1

Timed Interval—1 second to 24 hours for Data Log 1, and 1 minute to 24 hours for Data

Logs 2, 3 and 4 (how often the values are logged)

•

First-In-First-Out (FIFO) or Fill and Hold

Values to be logged—up to 96 registers along with the date and time of each log entry

START/STOP Time—each log has the ability to start and stop at a certain time during

the day

The default registers for Data Log 1 are listed in Table 7–5 below.

Table 7–5: Default Data Log 1 Register List

Number of

Description

Data Type➀ Register Number

Registers

Start Date/Time

D/T

integer

Current D/T

1100

1101

1102

1103

1120

1121

1122

1124

1125

1126

1160

1161

1162

1163

Current, Phase A

Current, Phase B

Current, Phase C

Current, Neutral

integer

Voltage A-B

integer

Voltage B-C

integer

Voltage C-A

integer

Voltage A-N

integer

Voltage B-N

integer

Voltage C-N

integer

True Power Factor, Phase A

True Power Factor, Phase B

True Power Factor, Phase C

True Power Factor, Total

signed integer

Last Demand, Current,

3-Phase Average

integer

2000

2150

2165

2180

Last Demand, Real Power,

3-Phase Total

Last Demand, Reactive

Power, 3-Phase Total

Last Demand, Apparent

Power 3-Phase Total

➀ Refer to Appendix A for more information about data types.

Use PowerLogic software to clear each data log file, independently of the others, from the

power meter’s memory. For instructions on setting up and clearing data log files, refer to

the PowerLogic software online help or documentation.

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Chapter 7—Logging

Alarm-driven Data Log Entries

The PM810 with a PM810LOG can detect over 50 alarm conditions, including over/under

conditions, digital input changes, phase unbalance conditions, and more. (See Chapter

6—Alarms on page 45 for more information.) Use PowerLogic software to assign each

alarm condition one or more tasks, including forcing data log entries into Data Log 1.

The PM820, PM850, and PM870 can detect over 50 alarm conditions, including over/under

conditions, digital input changes, phase unbalance conditions, and more. (See Chapter

6—Alarms on page 45 for more information.) Use PowerLogic software to assign each

alarm condition one or more tasks, including forcing data log entries into one or more data

log files.

For example, assume you have defined three data log files. Using PowerLogic software,

you could select an alarm condition such as “Overcurrent Phase A” and set up the power

meter to force data log entries into any of the three log files each time the alarm condition

occurs.

Organizing Data Log Files (PM850, PM870)

You can organize data log files in many ways. One possible way is to organize log files

according to the logging interval. You might also define a log file for entries forced by alarm

conditions. For example, you could set up three data log files as follows:

Data Log 1:

Data Log 2:

Data Log 3:

Log voltage every minute. Make the file large

enough to hold 60 entries so that you could look

back over the last hour’s voltage readings.

Log energy once every day. Make the file large

enough to hold 31 entries so that you could look

back over the last month and see daily energy use.

Report by exception. The report by exception file

contains data log entries that are forced by the

occurrence of an alarm condition. See the topic

above, “Alarm-driven Data Log Entries”, for more

information.

NOTE: The same data log file can support both scheduled and alarm-driven entries.

Billing Log

The PM810 with a PM810LOG, PM820, PM850 and PM870 Power Meters store a

configurable billing log that updates every 10 to 1,440 minutes (the default interval 60

minutes). Data is stored by month, day, and the specified interval in minutes. The log

contains 24 months of monthly data and 32 days of daily data, but because the maximum

amount of memory for the billing log is 64 KB, the number of recorded intervals varies

based on the number of registers recorded in the billing log. For example, using all of the

registers listed in Table 7–6, the billing log holds 12 days of data at 60-minute intervals.

This value is calculated by doing the following:

1. Calculate the total number of registers used (see Table 7–6 on page 63 for the number

of registers). In this example, all 26 registers are used.

2. Calculate the number of bytes used for the 24 monthly records.

24 records (26 registers x 2 bytes/register) = 1,248

3. Calculate the number of bytes used for the 32 daily records.

32 (26 x 2) = 1,664

4. Calculate the number of bytes used each day (based on 15 minute intervals).

96 (26 x 2) = 4,992

5. Calculate the number of days of 60-minute interval data recorded by subtracting the

values from steps 2 and 3 from the total log file size of 65,536 bytes and then dividing

by the value in step 4.

^{(65,536 – 1,248 – 1,664)}4,992 = 12 days

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Chapter 7—Logging

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Chapter 7—Logging

Table 7–6: Billing Log Register List

Number of

Description

Data Type➀ Register Number

Registers

Start Date/Time

D/T

Current D/T

1700

Real Energy In

MOD10L4

INT16

Reactive Energy In

Real Energy Out

1704

1708

Reactive Energy Out

Apparent Energy Total

Total PF

1712

1724

1163

3P Real Power Demand

3P Apparent Power Demand

INT16

2151

INT16

2181

➀ Refer to Appendix A for more information about data types.

Configure the Billing Log Logging Interval

The billing log can be configured to update every 10 to 1,440 minutes. The default logging

interval is 60 minutes. To set the logging interval you can use PowerLogic software, or you

can use the power meter to write the logging interval to register 3085 (see “Read and

Write Registers” on page 26).

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Chapter 8—Waveform Capture

Introduction

This section explains the waveform capture capabilities of the following Power Meter

models:

•

PM850

PM870

See Table 8–1 for a summary of waveform capture features.

Table 8–1: Waveform capture summary by model

Waveform Capture Feature

PM850

PM870

Number of waveform captures

Waveform initiated:

Manually



By alarm



Samples per cycle

Channels (1 to 6)

Cycles

128

Configurable*

Configurable

Precycles

* See Figure 8–1.

Waveform Capture

A waveform capture can be initiated manually or by an alarm trigger to analyze steady-

state or disturbance events. This waveform provides information about individual

harmonics, which PowerLogic software calculates through the 63rd harmonic. It also

calculates total harmonic distortion (THD) and other power quality parameters.

NOTE: Disturbance waveform captures are available in the PM870 only.

In the PM850, the waveform capture records five individual three-cycle captures at 128

samples per cycle simultaneously on all six metered channels. In the PM870, there is a

range of one to five waveform captures, but the number of cycles captured varies based on

the number of samples per cycle and the number of channels selected in your software.

Use Figure 8–1 to determine the number of cycles captured.

Figure 8–1: PM870 Number of Cycles Captured

Number

Channels

185

128

Number of Samples per Cycle

NOTE: The number of cycles shown above are the total number of cycles allowed (pre-

event cycles + event cycles = total cycles).

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Chapter 8—Waveform Capture

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Initiating a Waveform

Using PowerLogic software from a remote PC, initiate a waveform capture manually by

selecting the power meter and issuing the acquire command. The software will

automatically retrieve the waveform capture from the power meter. You can display the

waveform for all three phases, or zoom in on a single waveform, which includes a data

block with extensive harmonic data. See your software’s online help or documentation for

instructions.

Waveform Storage

The power meter can store multiple captured waveforms in its non-volatile memory. The

number of waveforms stored is based on the number selected. There are a maximum of

five stored waveforms. All stored waveform data is retained on power loss.

Waveform Storage Modes

There are two ways to store waveform captures: “FIFO” and “Fill and Hold.” FIFO mode

allows the file to fill up the waveform capture file. After the file is full, the oldest waveform

capture is removed, and the most recent waveform capture is added to the file. The Fill and

Hold mode fills the file until the configured number of waveform captures is reached. New

waveform captures cannot be added until the file is cleared.

How the Power Meter Captures an Event

When the power meter senses the trigger—that is, when the digital input transitions from

OFF to ON, or an alarm condition is met—the power meter transfers the cycle data from its

data buffer into the memory allocated for event captures.

Channel Selection in PowerLogic Software

Using PowerLogic software, you can select up to six channels to include in the waveform

capture. See your software’s online help or documentation for instructions.

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Chapter 9—Disturbance Monitoring (PM870)

This chapter provides background information about disturbance monitoring and describes

how to use the PM870 to continuously monitor for disturbances on the current and voltage

inputs.

About Disturbance Monitoring

Momentary voltage disturbances are an increasing concern for industrial plants, hospitals,

data centers, and other commercial facilities because modern equipment used in those

facilities tends to be more sensitive to voltage sags, swells, and momentary interruptions.

The power meter can detect these events by continuously monitoring and recording current

and voltage information on all metered channels. Using this information, you can diagnose

equipment problems resulting from voltage sags or swells and identify areas of

vulnerability, enabling you to take corrective action.

The interruption of an industrial process because of an abnormal voltage condition can

result in substantial costs, which manifest themselves in many ways:

•

labor costs for cleanup and restart

lost productivity

damaged product or reduced product quality

delivery delays and user dissatisfaction

The entire process can depend on the sensitivity of a single piece of equipment. Relays,

contactors, adjustable speed drives, programmable controllers, PCs, and data

communication networks are all susceptible to power quality problems. After the electrical

system is interrupted or shut down, determining the cause may be difficult.

Several types of voltage disturbances are possible, each potentially having a different

origin and requiring a separate solution. A momentary interruption occurs when a protective

device interrupts the circuit that feeds a facility. Swells and over-voltages can damage

equipment or cause motors to overheat. Perhaps the biggest power quality problem is the

momentary voltage sag caused by faults on remote circuits.

A voltage sag is a brief (1/2 cycle to 1 minute) decrease in rms voltage magnitude. A sag is

typically caused by a remote fault somewhere on the power system, often initiated by a

lightning strike. In Figure 9–1, the utility circuit breaker cleared the fault near plant D. The

fault not only caused an interruption to plant D, but also resulted in voltage sags to plants A,

B, and C.

NOTE: The PM870 is able to detect sag and swell events less than 1/2 cycle duration.

However, it may be impractical to have setpoints more sensitive than 10% for voltage and

current fluctuations.

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Chapter 9—Disturbance Monitoring (PM870)

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Figure 9–1: A fault can cause a voltage sag on the whole system

Utility Circuit

Breakers with

Reclosers

Plant A

Plant B

Plant C

Utility

Transformer

Plant D

Fault

A fault near plant D, cleared by the utility circuit

breaker, can still affect plants A, B, and C,

resulting in a voltage sag.

System voltage sags are much more numerous than interruptions, since a wider part of the

distribution system is affected. And, if reclosers are operating, they may cause repeated

sags. The PM870 can record recloser sequences, too. The waveform in Figure 9–2 shows

the magnitude of a voltage sag, which persists until the remote fault is cleared.

Figure 9–2: Waveform showing voltage sag caused by a remote fault and lasting five cycles

With the information obtained from the PM870 during a disturbance, you can solve

disturbance-related problems, including the following:

•

Obtain accurate measurement from your power system

— Identify the number of sags, swells, or interruptions for evaluation

— Accurately distinguish between sags and interruptions, with accurate recording of

the time and date of the occurrence

— Provide accurate data in equipment specification (ride-through, etc.)

Determine equipment sensitivity

•

— Compare equipment sensitivity of different brands (contactor dropout, drive

sensitivity, etc.)

— Diagnose mysterious events such as equipment malfunctions, contactor dropout,

computer glitches, etc.

— Compare actual sensitivity of equipment to published standards

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Chapter 9—Disturbance Monitoring (PM870)

— Use waveform capture to determine exact disturbance characteristics to compare

with equipment sensitivity

— Justify purchase of power conditioning equipment

— Distinguish between equipment malfunctions and power system related problems

•

Develop disturbance prevention methods

— Develop solutions to voltage sensitivity-based problems using actual data

Work with the utility

— Discuss protection practices with the serving utility and negotiate suitable changes

to shorten the duration of potential sags (reduce interruption time delays on

protective devices)

— Work with the utility to provide alternate “stiffer” services (alternate design practices)

Capabilities of the PM870 During an Event

The PM870 calculates rms magnitudes, based on 128 data points per cycle, every 1/2

cycle. This ensures that even sub-cycle duration rms variations are not missed.

The power meter is configured with 12 default voltage disturbance alarms for all voltage

channels. Current sag and swell alarms are available by configuring custom alarms. A

maximum of 12 disturbance alarms are available. When the PM870 detects a sag or swell,

it can perform the following actions:

•

Perform a waveform capture with a resolution from 185 cycles at 16 samples per

cycle on one channel down to 3 cycles at 128 samples per cycle on all six channels of

the metered current and voltage inputs (see Figure 8–1 on page 63). Use PowerLogic

software to set up the event capture and retrieve the waveform.

•

Record the event in the alarm log. When an event occurs, the PM870 updates the

alarm log with an event date and time stamp with 1 millisecond resolution for a sag or

swell pickup, and an rms magnitude corresponding to the most extreme value of the

sag or swell during the event pickup delay. Also, the PM870 can record the sag or swell

dropout in the alarm log at the end of the disturbance. Information stored includes: a

dropout time stamp with 1 millisecond resolution and a second rms magnitude

corresponding to the most extreme value of the sag or swell. Use PowerLogic software

to view the alarm log.

NOTE: The Power Meter display has a 1 second resolution.

•

Force a data log entry in up to 3 independent data logs. Use PowerLogic software to

set up and view the data logs.

•

Operate any output relays when the event is detected.

Indicate the alarm on the display by flashing the maintenance icon to show that a sag

or swell event has occurred.

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Chapter 9—Disturbance Monitoring (PM870)

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Chapter 10—Maintenance and Troubleshooting

Introduction

This chapter describes information related to maintenance of your power meter.

The power meter does not contain any user-serviceable parts. If the power meter requires

service, contact your local sales representative. Do not open the power meter. Opening the

power meter voids the warranty.

DANGER

HAZARD OF ELECTRIC SHOCK, EXPLOSION, OR ARC FLASH

• Do not attempt to service the power meter. CT and PT inputs may contain

hazardous currents and voltages.

• Only authorized service personnel from the manufacturer should service the

power meter.

Failure to follow these instructions will result in death or serious injury.

CAUTION

HAZARD OF EQUIPMENT DAMAGE

• Do not perform a Dielectric (Hi-Pot) or Megger test on the power meter. High

voltage testing of the power meter may damage the unit.

• Before performing Hi-Pot or Megger testing on any equipment in which the power

meter is installed, disconnect all input and output wires to the power meter.

Failure to follow these instructions can result in injury or equipment damage.

Power Meter Memory

The power meter uses its non-volatile memory (RAM) to retain all data and metering

configuration values. Under the operating temperature range specified for the power meter,

this non-volatile memory has an expected life of up to 100 years. The power meter stores

its data logs on a memory chip, which has a life expectancy of up to 20 years under the

operating temperature range specified for the power meter. The life of the internal battery-

backed clock is over 10 years at 25°C.

NOTE: Life expectancy is a function of operating conditions; this does not constitute any

expressed or implied warranty.

Date and Time Settings

The clock in the PM810 is volatile. Therefore, the PM810 returns to the default clock

date/time of 12:00 AM 01-01-1980 each time the meter resets. Reset occurs when the

meter loses control power or you change meter configuration parameters including

selecting the time format (24-hr or AM/PM) or date format. To avoid resetting clock time

more than once, always set the clock date and time last. The PM810LOG (optional module)

provides a non-volatile clock in addition to on-board logging and individual harmonics

readings for the PM810.

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Chapter 10—Maintenance and Troubleshooting

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Identifying the Firmware Version, Model, and Serial Number

1. From the first menu level, press ###:until

MAINT is visible.

ꢅꢄꢚꢄꢇꢆꢊꢕꢮꢝ

ꢈꢂꢆ

ꢉꢀꢅꢉꢆꢆ

ꢉꢆꢅꢋꢆꢆ

ꢀꢂꢆꢆꢆꢉꢊꢁ

2. Press DIAG.

3. Press METER.

ꢀꢆꢅ

ꢅꢝꢋꢄꢨ

ꢖꢌꢗꢌ

4. View the model, firmware (OS) version,

and serial number.

ꢆꢆꢬ

5. Press 1;to return to the MAINTENANCE

screen.

ꢇꢄꢃꢄꢚ

ꢃꢌꢕꢌ

ꢈꢉ

ꢙꢍ

ꢍꣅ

Viewing the Display in Different Languages

The power meter can be set to use one of five different languages: English, French, and

Spanish. Other languages are available. Please contact your local sales representative for

more information about other language options.

The power meter language can be selected by doing the following:

1. From the first menu level, press ###:until

MAINT is visible.

ꢨꢂꢕꢩꢛꢂꢩꢄ

2. Press MAINT.

3. Press SETUP.

ꢄꢕꢩꢨꢌ

4. Enter your password, then press OK.

5. Press ###:until LANG is visible.

6. Press LANG.

7. Select the language: ENGL (English),

FREN (French), SPAN (Spanish), GERMN

(German), or RUSSN (Russian).

ꢈꢉ

ꢙꢍ

ꢜ

ꢝꢞ

8. Press OK.

9. Press1;.

10. Press YES to save your changes.

Technical Support

For assistance with technical issues, contact your local Schneider Electric representative.

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Chapter 10—Maintenance and Troubleshooting

Troubleshooting

The information in Table 10–1 on page 72 describes potential problems and their possible

causes. It also describes checks you can perform or possible solutions for each. If you still

cannot resolve the problem after referring to this table, contact the your local Schneider

Electric sales representative for assistance.

DANGER

HAZARD OF ELECTRIC SHOCK, EXPLOSION, OR ARC FLASH

• Apply appropriate personal protective equipment (PPE) and follow safe

electrical practices. For example, in the United States, see NFPA 70E.

• This equipment must be installed and serviced only by qualified personnel.

• Turn off all power supplying this equipment before working on or inside.

• Always use a properly rated voltage sensing device to confirm that all power is

off.

• Carefully inspect the work area for tools and objects that may have been left

inside the equipment.

• Use caution while removing or installing panels so that they do not extend into

the energized bus; avoid handling the panels which could cause personal injury.

Failure to follow these instructions will result in death or serious injury.

Heartbeat LED

The heartbeat LED helps to troubleshoot the power meter. The LED works as follows:

•

Normal operation — the LED flashes at a steady rate during normal operation.

Communications — the LED flash rate changes as the communications port transmits

and receives data. If the LED flash rate does not change when data is sent from the

host computer, the power meter is not receiving requests from the host computer.

•

Hardware — if the heartbeat LED remains lit and does not flash ON and OFF, there is

a hardware problem. Do a hard reset of the power meter (turn OFF power to the power

meter, then restore power to the power meter). If the heartbeat LED remains lit, contact

your local sales representative.

Control power and display — if the heartbeat LED flashes, but the display is blank,

the display is not functioning properly. If the display is blank and the LED is not lit, verify

that control power is connected to the power meter.

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Chapter 10—Maintenance and Troubleshooting

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Table 10–1: Troubleshooting

Potential Problem

Possible Cause

Possible Solution

Go to DIAGNOSTICS > MAINTENANCE.

Error messages display to indicate the

reason the icon is illuminated. Note these

When the maintenance icon is

illuminated, it indicates a potential

The maintenance icon is

illuminated on the power

meter display.

hardware or firmware problem in the error messages and call Technical

power meter.

Support, or contact your local sales

representative for assistance.

The display shows error

code 3.

Loss of control power or meter

configuration has changed.

Set date and time.

•

Verify that the power meter line (L) and

neutral (N) terminals (terminals 25 and

27) are receiving the necessary power.

Verify that the heartbeat LED is

blinking.

The display is blank after

applying control power to

the power meter.

The power meter may not be

receiving the necessary power.

Verify that the power meter is grounded as

Power meter is grounded incorrectly. described in “Grounding the Power Meter”

in the installation manual.

Check that the correct values have been

entered for power meter setup parameters

Incorrect setup values.

Incorrect voltage inputs.

(CT and PT ratings, System Type, Nominal

Frequency, and so on). See “Power Meter

Setup” on page 13 for setup instructions.

The data being displayed is

inaccurate or not what you

expect.

Check power meter voltage input terminals

L (8, 9, 10, 11) to verify that adequate

voltage is present.

Check that all CTs and PTs are connected

correctly (proper polarity is observed) and

that they are energized. Check shorting

terminals. See “Instrument Transformer

Wiring: Troubleshooting Tables” on

page 73. Initiate a wiring check using

PowerLogic software.

Power meter is wired improperly.

Check to see that the power meter is

correctly addressed. See “COMMS

(Communications) Setup” on page 15 for

instructions.

Power meter address is incorrect.

Power meter baud rate is incorrect.

Verify that the baud rate of the power

meter matches the baud rate of all other

devices on its communications link. See

“COMMS (Communications) Setup” on

page 15 for instructions.

Cannot communicate with

power meter from a remote

personal computer.

Verify the power meter communications

connections. Refer to the PM800-Series

Installation Guide.

Communications lines are improperly

connected.

Check to see that a multipoint

Communications lines are improperly communications terminator is properly

terminated.

installed. Refer to the PM800-Series

Installation Guide.

Check the route statement. Refer to your

software online help or documentation for

instructions on defining route statements.

Incorrect route statement to power

meter.

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Appendix A—Instrument Transformer Wiring: Troubleshooting Tables

Abnormal readings in an installed meter can sometimes signify improper wiring. This

appendix is provided as an aid in troubleshooting potential wiring problems.

Using This Appendix

The following pages contain “Case” tables arranged in sections. These tables show a

variety of symptoms and probable causes.

Section I: Check these tables first. These are common problems for 3-wire and 4-wire

systems that can occur regardless of system type.

Section II: Check these tables if troubleshooting more complex 3-wire systems.

Section III: Check these tables if troubleshooting more complex 4-wire systems.

The symptoms listed are “ideal,” and some judgment should be exercised when

troubleshooting. For example, if the kW reading is 25, but you know that it should be about

300 kW, go to a table where “kW = 0” is listed as one of the symptoms.

Because it is nearly impossible to address all combinations of multiple wiring mistakes or

other problems that can occur (e.g., blown PT fuses, missing PT neutral ground

connection), this guide generally addresses only one wiring problem at a time.

Before trying to troubleshoot wiring problems, it is imperative that all instantaneous

readings be available for reference. Specifically, those readings should include the

following:

•

line-to-line voltages

line-to-neutral voltages

phase currents

power factor

kVAR

kVA

What is Normal?

Most power systems have a lagging (inductive) power factor. The only time a leading power

factor is expected is if power factor correction capacitors are switched in or over-excited

synchronous motors with enough capacitive kVARS are on-line to overcorrect the power

factor to leading. Some uninterruptable power supplies (UPS) also produce a leading

power factor.

"Normal" lagging power system readings are as follows:

•

Positive kW =  3  V_AB I_3Avg PF_3Avg  1000

Negative kVAR =  kVA²– kW²  1000

kVA (always positive) =  3  V_AB I_3Avg  1000

PF_3Avg= lagging in the range 0.70 to 1.00 (for 4-wire systems, all phase PFs are

about the same)

•

Phase currents approximately equal

Phase voltages approximately equal

A quick check for proper readings consists of kW comparisons (calculated using the

previous equation and compared to the meter reading) and a reasonable lagging 3-phase

average power factor reading. If these checks are okay, there is little reason to continue to

check for wiring problems.

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Appendix A—Instrument Transformer Wiring: Troubleshooting Tables

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Section I: Common Problems for 3-Wire and 4-Wire Systems

Section I—Case A

Symptoms: 3-Wire and 4-Wire

Possible Causes

•

CT secondaries shorted.

•

Zero amps

Less than 2% load on power meter based on CT ratio.

Zero kW, kVAR, kVA

Example: with 100/5 CT's, at least 2A must flow through CT window for power

meter to “wake up.”

Section I—Case B

Symptoms: 3-Wire and 4-Wire

Possible Causes

•

All three CT polarities backwards; could be CTs are physically mounted

with primary polarity mark toward the load instead of toward source or

secondary leads swapped.

•

Negative kW of expected magnitude

Positive kVAR

•

All three PT polarities backwards; again, could be on primary or secondary.

Normal lagging power factor

NOTE: Experience shows CTs are usually the problem.

Section I—Case C

Symptoms: 3-Wire and 4-Wire

Possible Causes

•

PTs primary and/or secondary neutral common not grounded (values as

high as 275 Hz and as low as 10 Hz have been seen).

•

Frequency is an abnormal value; may or may

not be a multiple of 50/60 Hz.

System grounding problem at the power distribution transformer (such as

utility transformer), though this is not likely.

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Appendix A—Instrument Transformer Wiring: Troubleshooting Tables

Section II: 3-Wire System Troubleshooting

Section II—Case A

Symptoms: 3-Wire

Possible Causes

•

Currents and voltages approximately balanced

kW = near 0

•

CT secondary leads are swapped (A-phase lead on C-phase terminal and

vice versa).

kVAR = near 0

PT secondary leads are swapped (A-phase lead on C-phase terminal and

vice versa).

PF can be any value, probably fluctuating

Section II—Case B

Symptoms: 3-Wire

Possible Causes

•

Phase B current is 3 higher than A and C

(except in System Type 31).

•

kVA = about half of the expected magnitude

•

One CT polarity is backwards.

kW and kVAR can be positive or negative, less

than about half of the expected magnitude.

•

PF can be any value, probably a low leading

value.

Section II—Case C

Symptoms: 3-Wire

Possible Causes

•

V_CAis 3 higher than V_ABand V_BC

kVA = about half of the expected magnitude

kW and kVAR can be positive or negative, less

than about half of the expected magnitude

•

One PT polarity is backwards.

•

PF can be any value, probably a low leading

value

Section II—Case D

Symptoms: 3-Wire

Possible Causes

•

kW = 0 or low, with magnitude less than kVAR

•

Either the two voltage leads are swapped OR the two current leads are

swapped AND one instrument transformer has backwards polarity.

kVAR = positive or negative with magnitude of

close to what is expected for kW

(look for V_CA

3 high or phase B current = 3 high)

•

kVA = expected magnitude

The power meter is metering a purely capacitive load (this is unusual); in

this case kW and kVAR will be positive and PF will be near 0 lead.

PF = near 0 up to about 0.7 lead

Section II—Case E

Symptoms: 3-Wire

Possible Causes

•

One phase current reads 0

•

The CT on the phase that reads 0 is short-circuited.

kVA = about 1/2 of the expected value

Less than 2% current (based on CT ratio) flowing through the CT on the

phase that reads 0.

kW, kVAR, and power factor can be positive or

negative of any value

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Appendix A—Instrument Transformer Wiring: Troubleshooting Tables

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Section III: 4-Wire System Troubleshooting

Section III—Case A

Symptoms: 4-Wire

Possible Causes

•

kW = 1/3 of the expected value

kVAR = 1/3 of the expected value

power factor = 1/3 of the expected value

All else is normal

•

One CT polarity is backwards.

NOTE: The only way this problem will usually be detected is by the Quick Check

procedure. It is very important to always calculate kW. In this case, it is the only symptom

and will go unnoticed unless the calculation is done or someone notices backwards CT on

a waveform capture.

Section III—Case B

Symptoms: 4-Wire

Possible Causes

•

One PT polarity is backwards.

•

kW = 1/3 of the expected value

kVAR = 1/3 of the expected value

2 of the 3 line-to-line voltages are 3 low

power factor = 1/3 of the expected value

All else is normal

NOTE: The line-to-line voltage reading that does not reference the PT with backwards

polarity will be the only correct reading.

Example: V_AB= 277, V_BC= 480, V_CA= 277

In this case, the A-phase PT polarity is backwards. V_BCis correct because it does not

reference V_A

Section III—Case C

Symptoms: 4-Wire

Possible Causes

•

One line-to-neutral voltage is zero

2 of the 3 line-to-line voltages are 3 low

kW = 2/3 of the expected value

kVAR = 2/3 of the expected value

kVA = 2/3 of the expected value

Power factor may look abnormal

•

PT metering input missing (blown fuse, open phase disconnect, etc.) on the

phase that reads zero.

NOTE: The line-to-line voltage reading that does not reference the missing PT input will be

the only correct reading.

Example: V_AB= 277, V_BC= 277, V_CA= 480

In this case, the B-phase PT input is missing. V_CAis correct because it does not

reference V_B

Section III—Case D

Symptoms: 4-Wire

Possible Causes

•

3-phase kW = 2/3 of the expected value

3-phase kVAR = 2/3 of the expected value

3-phase kVA = 2/3 of the expected value

One phase current reads 0

•

The CT on the phase that reads 0 is short-circuited.

Less than 2% current (based on CT ratio) flowing through the CT on the

phase that reads 0.

All else is normal

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Appendix A—Instrument Transformer Wiring: Troubleshooting Tables

Section III—Case E

Symptoms: 4-Wire

Possible Causes

•

kW = near 0

kVA = near 0

•

Two CT secondary leads are swapped (A-phase on B-phase terminal, for

example).

Two PT secondary leads are swapped (A-phase on B-phase terminal, for

example).

3-phase average power factor flip-flopping lead

and lag

NOTE: In either case, the phase input that is not swapped will read normal lagging power

factor.

•

Voltages, currents, and kVA are normal

Section III—Case F

Symptoms: 4-Wire

Possible Causes

•

kW = negative and less than kVAR

•

All three PT lead connections “rotated” counterclockwise: A-phase wire on

C-phase terminal, B-phase wire on A-phase terminal, C-phase wire on B-

phase terminal.

KVAR = negative and close to value expected

for kW

•

kVA = expected value

All three CT lead connections “rotated” clockwise: A-phase wire on B-phase

terminal, B-phase wire on C-phase terminal, C-phase wire on A-phase

terminal.

Power factor low and leading

Voltages and currents are normal

Section III—Case G

Symptoms: 4-Wire

Possible Causes

•

kW = negative and less than kVAR

•

All three PT lead connections “rotated” clockwise: A-phase wire on B-phase

terminal, B-phase wire on C-phase terminal, C-phase wire on A-phase

terminal.

kVAR = positive and close to the value for kW

NOTE: looks like kW and kVAR swapped places

•

All three CT lead connections “rotated” counterclockwise: A-phase wire on

C-phase terminal, B-phase wire on A-phase terminal, C-phase wire on B-

phase terminal.

•

kVA = expected value

Power factor low and lagging

Voltages and currents are normal

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Appendix A—Instrument Transformer Wiring: Troubleshooting Tables

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Field Example

Readings from a 4-wire system

•

kW= 25

kVAR= –15

kVA= 27

I_A= 904A

I_B= 910A

I_C= 931A

I_3Avg= 908A

V_AB= 495V

V_BC= 491V

V_CA= 491V

V_AN= 287V

V_BN= 287V

V_CN= 284V

PF_3Avg= 0.75 lag to 0.22 lead fluctuating

Troubleshooting Diagnosis

•

Power factors cannot be correct .

None of the “Section II” symptoms exist, so proceed to the 4-wire troubleshooting

(“Section IV”).

•

Cannot calculate kW because 3-phase power factor cannot be right, so calculate kVA

instead.

Calculated kVA =  3  V_ab I_3Avg  1000

= 1.732  495  908  1000

= 778 kVA

•

Power meter reading is essentially zero compared to this value.

4-wire Case E looks similar.

Since the PTs were connected to other power meters which were reading correctly,

suspect two CT leads swapped.

•

Since A-phase power factor is the only one that has a normal looking lagging value,

suspect B and C-phase CT leads may be swapped.

After swapping B and C-phase CT leads, all readings went to the expected values;

problem solved.

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Appendix B—Register List

The register list corresponding to the latest firmware version can be found on line at the

Schneider Electric website.

1. Using a web browser, go to: www.Schneider-Electric.com.

2. Locate the Search box in the upper right corner of the home page.

3. In the Search box enter “PM8”.

4. In the drop-down box click on the selection “PM800 series”.

5. Locate the downloads area on the right side of the page and click on

“Software/Firmware”.

6. Click on the applicable register list then download the document file indicated.

In addition you will find the latest firmware files and a firmware history file that describes the

enhancements for each of the different firmware releases.

About Registers

For registers defined in bits, the rightmost bit is referred to as bit 00. Figure B–1 shows how

bits are organized in a register.

Figure B–1: Bits in a register

High Byte

Low Byte

Bit No.

15 14 13 12 11 10 09 08 07 06 05 04 03 02 01

The power meter registers can be used with MODBUS or JBUS protocols. Although the

MODBUS protocol uses a zero-based register addressing convention and JBUS protocol

uses a one-based register addressing convention, the power meter automatically

compensates for the MODBUS offset of one. Regard all registers as holding registers

where a 30,000 or 40,000 offset can be used. For example, Current Phase A will reside in

Floating-point Registers

Floating-point registers are also available. To enable floating-point registers, see “Enabling

Floating-point Registers” on page 91.

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Appendix B—Register List

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How Date and Time are Stored in Registers

The date and time are stored in a three-register compressed format. Each of the three

registers, such as registers 1810 to 1812, contain a high and low byte value to represent

the date and time in hexadecimal. Table B–1 lists the register and the portion of the date or

time it represents.

Table B–1: Date and Time Format

Hi Byte

Lo Byte

Month (1-12)

Day (1-31)

Year (0-199)

Minute (0-59)

Hour (0-23)

Second (0-59)

Table B–2 provides an example of the date and time. If the date was 01/25/00 at 11:06:59,

the Hex value would be 0119, 640B, 063B. Breaking it down into bytes we have the

following:

Table B–2: Date and Time Byte Example

Hexadecimal Value

Hi Byte

Lo Byte

0119

01 = month

19 = day

640B

063B

64 = year

0B = hour

06 = minute

3B = seconds

NOTE: Date format is a 3 (6-byte) register compressed format. (Year 2001 is represented

as 101 in the year byte.)

How Signed Power Factor is Stored in the Register

Each power factor value occupies one register. Power factor values are stored using

signed magnitude notation (see Figure B–2). Bit number 15, the sign bit, indicates

leading/lagging. A positive value (bit 15=0) always indicates leading. A negative value (bit

15=1) always indicates lagging. Bits 0–9 store a value in the range 0–1,000 decimal. For

example the power meter would return a leading power factor of 0.5 as 500. Divide by

1,000 to get a power factor in the range 0 to 1.000.

Figure B–2: Power Factor Register Format

15 14 13 12 11 10

Unused Bits

Set to 0

Power Factor

in the range 100-1000 (thousandths)

Sign Bit

0=Leading

1=Lagging

When the power factor is lagging, the power meter returns a high negative value—for

example, -31,794. This happens because bit 15=1 (for example, the binary equivalent of -

31,794 is 1000001111001110). To get a value in the range 0 to 1,000, you need to mask bit

15. You do this by adding 32,768 to the value. An example will help clarify.

Assume that you read a power factor value of -31,794. Convert this to a power factor in the

range 0 to 1.000, as follows:

-31,794 + 32,768 = 974

974/1,000 = .974 lagging power factor

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Appendix B—Register List

Supported Modbus Commands

Table B–3 provides the Modbus commands that the PM800 Series meters support. For an

up-to-date register list, see ““Register List Access”” at the start of this chapter.

Table B–3: Modbus Commands

Command

Description

0x03

0x04

0x06

0x10

Read holding registers

Read input registers

Preset single registers

Preset multiple registers

Report ID

Return String

byte 1: 0x11

byte 2: number of bytes following without crc

byte 3: ID byte = 250

0x11

byte 4: status = 0xFF

bytes 5+: ID string = PM8xx Power Meter

last 2 bytes: CRC

Read device identification, BASIC implementation (0x00, 0x01, 0x02 data),

conformity level 1,

Object Values

0x01: If register 4128 is 0, then “Schneider Electric. If register 4128 is 1,

then “Square D”

0x2B

0x02: “PM8xx”

0x03: “Vxx.yyy” where xx.yyy is the OS version number. This is the

reformatted version of register 7001. If the value for register 7001 is 11900,

then the 0x03 data would be “V11.900”

Resetting Registers

Table B–4 provides the commands needed to reset many of the power meter features. You

can perform these resets simply by writing the commands into register 4126.

Table B–4: Register Listing—Reset Commands

Reset Commands—Write commands to Register 4126.

Command

666

Parameters

Notes

Restart demand metering

1115

Reset Meter

3211

Reset all alarms to default values

De-energize digital output

Energize digital output

3320

3321

3361

Reset digital output counter

Reset digital input counters

3365

7016

7017

7018

7019

7020

7021

4000

4001

4002

4003

4004

4005

6209

Preset Energy Values

10001

14255

21212

30078

Clear the Usage Timers. (Set to 0)

Reset all Min/Max Values. (Sets values to defaults)

Reset Peak Demand values. (Set to 0)

Clear all Energy Accumulators. (Set to 0)

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Appendix B—Register List

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Appendix C—Using the Command Interface

Overview of the Command Interface

The power meter provides a command interface, which can be used to issue commands

that perform various operations such as controlling relays. Table C–1 lists the definitions for

the registers.Table C–2 lists the available commands. The command interface is located in

memory at registers 8000–8149.

Table C–1: Location of the command interface

Description

8000

This is the register where you write the commands.

These are the registers where you write the parameters for a

command. Commands can have up to 15 parameters associated with

them.

8001–8015

Command pointer. This register holds the register number where the

most recently entered command is stored.

8017

8018

8019

Results pointer. This register holds the register number where the

results of the most recently entered command are stored.

I/O data pointer. Use this register to point to data buffer registers

where you can send additional data or return data.

These registers are for you (the user) to write information. Depending

on which pointer places the information in the register, the register can

contain status (from pointer 8017), results (from pointer 8018), or data

(from pointer 8019). The registers will contain information such as

whether the function is enabled or disabled, set to fill and hold, start

and stop times, logging intervals, and so forth.

8020–8149

By default, return data will start at 8020 unless you specify otherwise.

When registers 8017 through 8019 are set to zero, no values are returned. When any or all

of these registers contain a value, the value in the register “points” to a target register,

which contains the status, error code, or I/O data (depending on the command) when the

command is executed. Figure C–1 shows how these registers work.

NOTE: You determine the register location where results will be written. Therefore, take

care when assigning register values in the pointer registers; values may be corrupted when

two commands use the same register.

Figure C–1: Command interface pointer registers

(status of the

last command)

(error code caused by

the last command)

(data returned by the

last command)

Refer to “Register List Access” on page 79 for instructions on accessing the complete register list.

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Appendix C—Using the Command Interface

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Issuing Commands

To issue commands using the command interface, follow these general steps:

1. Write the related parameter(s) to the command parameter registers 8001–15.

2. Write the command code to command interface register 8000.

If no parameters are associated with the command, then you need only to write the

command code to register 8000. Table C–2 lists the command codes that can be written to

the command interface into register 8000. Some commands have an associated register

where you write parameters for that command. For example, when you write the parameter

9999 to register 8001 and issue command code 3351, all relays will be energized if they are

set up for external control.

Table C–2: Command Codes

Command

Code

Parameter

Parameters

Description

Causes soft reset of the unit (re-initializes the

power meter).

1110

1210

1310

None

Clears the communications counters.

Sets the system date and time. Values for the

registers are:

8001

8002

8003

8004

8005

8006

Month

Day

Month (1–12)

Day (1–31)

Year

Year (4-digit, for example 2000)

Hour (Military time, for example 14 = 2:00pm)

Minute (1–59)

Hour

Minute

Second

Second (1–59)

1410

1411

None

Disables the revenue security switch

Enables the revenue security switch

Relay Outputs

3310

3311

3320

3321

8001

Relay Output Number ➀ Configures relay for external control.

Relay Output Number ➀ Configures relay for internal control.

Relay Output Number ➀ De-energizes designated relay.

Relay Output Number ➀ Energizes designated relay.

Releases specified relay from latched

condition.

3330

8001

Relay Output Number ➀

3340

3341

3350

3351

3361

3362

3363

3364

8001

Relay Output Number ➀ Releases specified relay from override control.

Relay Output Number ➀ Places specified relay under override control.

9999

De-energizes all relays.

Energizes all relays.

Relay Output Number ➀ Resets operation counter for specified relay.

Relay Output Number ➀ Resets the turn-on time for specified relay.

None

Resets the operation counter for all relays.

Resets the turn-on time for all relays.

Resets the operation counter for specified

input.

3365

8001

Input Number ➀

3366

3367

3368

3369

3370

3371

3380

3381

8001

8002

Input Number ➀

None

Resets turn-on time for specified input.

Resets the operation counter for all inputs.

Resets turn-on time for all inputs.

None

Resets all counters and timers for all I/Os.

Analog Output Number ➀ Disables specified analog output.

Analog Output Number ➀ Enables specified analog output.

9999

Disables all analog outputs.

Enables all analog outputs.

➀ You must write to register 8001 the number that identifies which output you would like to use. To determine

the identifying number, refer to“I/O Point Numbers” on page 86 for instructions.

➁ Data buffer location (register 8019) is the pointer to the first register where data will be stored. By default,

return data begins at register 8020, although you can use any of the registers from 8020–8149. Take care when

assigning pointers. Values may be corrupted if two commands are using the same register.

Refer to “Register List Access” on page 79 for instructions on accessing the complete register list.

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Appendix C—Using the Command Interface

Table C–2: Command Codes

Command

Parameter

Parameters

Description

Code

Resets

1522

None

8001

None

Resets the alarm history log.

Resets min/max.

0 = Present and previous

months

4110

1 = Present month

2 = Previous month

None

5110

5111

5113

5114

None

Resets all demand registers.

Resets current demand.

Resets power demand.

Resets input demand.

None

Resets generic demand for first group of 10

quantities.

5115

None

5210

5211

5213

5214

5215

None

Resets all min/max demand.

Resets current min/max demand.

Resets power min/max demand.

Resets input min/max demand.

Resets generic 1 min/max demand.

Start new demand interval.

Bit 0 = Power Demand

5910

6209

8001

8019

Bitmap

1 = Current Demand

2 = Input Metering Demand

3 = Generic Demand Profile

Preset Accumulated Energies

Requires the IO Data Pointer to point to

registers where energy preset values are

entered. All Accumulated energy values must

be entered in the order in which they occur in

registers 1700 to 1727.

I/O Data Pointer ➁

6210

6211

6212

6213

6214

None

Clears all energies.

Clears all accumulated energy values.

Clears conditional energy values.

Clears incremental energy values.

Clears input metering accumulation.

Resets the following parameters to IEEE or

IEC defaults:

1. Phase labels

2. Menu labels

3. Harmonic units

4. PF sign

1 = IEEE

2 = IEC

6215

None

5. THD denominator

6. Date Format

6320

6321

6910

None

Disables conditional energy accumulation.

Enables conditional energy accumulation.

Starts a new incremental energy interval.

Files

Triggers data log entry. Bitmap where Bit 0 =

Data Log 1, Bit 1 = Data Log 2, Bit 2 = Data

Log 3, etc.

7510

7511

8001

1–3

File Number

Triggers single data log entry.

➀ You must write to register 8001 the number that identifies which output you would like to use. To determine

the identifying number, refer to“I/O Point Numbers” on page 86 for instructions.

➁ Data buffer location (register 8019) is the pointer to the first register where data will be stored. By default,

return data begins at register 8020, although you can use any of the registers from 8020–8149. Take care when

assigning pointers. Values may be corrupted if two commands are using the same register.

Refer to “Register List Access” on page 79 for instructions on accessing the complete register list.

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Appendix C—Using the Command Interface

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Table C–2: Command Codes

Command

Parameter

Command

Code

Parameters

Description

Setup

9020

None

8001

None

Enter into setup mode.

Exit setup mode and save all changes.

1 = Save

9021

2 = Do not save

➀ You must write to register 8001 the number that identifies which output you would like to use. To determine

the identifying number, refer to“I/O Point Numbers” on page 86 for instructions.

➁ Data buffer location (register 8019) is the pointer to the first register where data will be stored. By default,

return data begins at register 8020, although you can use any of the registers from 8020–8149. Take care when

assigning pointers. Values may be corrupted if two commands are using the same register.

Refer to “Register List Access” on page 79 for instructions on accessing the complete register list.

I/O Point Numbers

All inputs and outputs of the power meter have a reference number and a label that

correspond to the position of that particular input or output.

•

The reference number is used to manually control the input or output with the command

interface.

The label is the default identifier that identifies that same input or output. The label

appears on the display, in PowerLogic software, and on the option card.

See Table C–3 for a complete list of I/O Point Numbers

Table C–3: I/O Point Numbers

Module

Standard I/O

PM8M22 PM8M26 PM8M2222

I/O Point Number

—

A-R1

A-R2

A-S1

A-S2

A-S3

A-S4

A-S5

A-S6

A-R1

A-R2

A-S1

A-R1

A-R2

A-S1

A-S2

—

A-AI1

A-AI2

A-AO1

A-AO2

B-R1

B-R2

B-S1

B-S2

B-S3

B-S4

B-S5

B-S6

B-R1

B-R2

B-S1

B-R1

B-R2

B-S1

B-S2

B-AI1

B-AI2

B-AO1

B-AO2

Operating Outputs from the Command Interface

To operate an output from the command interface, first identify the relay using the I/O point

number. Then, set the output to external control. For example, to energize output 1, write

the commands as follows:

1. Write number 1 to register 8001.

2. Write command code 3310 to register 8000 to set the relay to external control.

3. Write command code 3321 to register 8000.

If you look in the “Relay Outputs” section of Table C–2 on page 84, you’ll see that

command code 3310 sets the relay to external control and command code 3321 is listed as

the command used to energize a relay. Command codes 3310–3381 are for use with inputs

and outputs.

Refer to “Register List Access” on page 79 for instructions on accessing the complete register list.

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Appendix C—Using the Command Interface

Using the Command Interface to Change Configuration Registers

You can also use the command interface to change values in selected metering-related

registers, such as setting the time of day of the clock or resetting generic demand.

Two commands, 9020 and 9021, work together as part of the command interface

procedure when you use it to change power meter configuration. You must first issue

command 9020 to enter into setup mode, change the register, and then issue 9021 to save

your changes and exit setup mode.

Only one setup session is allowed at a time. While in this mode, if the power meter detects

more than two minutes of inactivity, that is, if you do not write any register values or press

any buttons on the display, the power meter will time out and restore the original

configuration values. All changes will be lost. Also, if the power meter loses power or

communications while in setup mode, your changes will be lost.

The general procedure for changing configuration registers using the command interface is

as follows:

1. Issue command 9020 in register 8000 to enter into setup mode.

2. Make changes to the appropriate register by writing the new value to that register.

Perform register writes to all registers that you want to change. For instructions on

reading and writing registers, see “Read and Write Registers” on page 26.

3. To save the changes, write the value 1 to register 8001.

NOTE: Writing any other value except 1 to register 8001 lets you exit setup mode

without saving your changes.

4. Issue command 9021 in register 8000 to initiate the save and reset the power meter.

For example, the procedure to change the demand interval for current is as follows:

1. Issue command code 9020 in register 8000.

2. Write the new demand interval to register 1801.

3. Write 1 to register 8001.

4. Issue command code 9021 in register 8000.

Refer to “Register List Access” on page 79 for instructions on accessing the complete

Conditional Energy

Power meter registers 1728–1744 are conditional energy registers.

Conditional energy can be controlled in one of two ways:

•

Over the communications link, by writing commands to the power meter’s command

interface, or

•

By a digital input—for example, conditional energy accumulates when the assigned

digital input is on, but does not accumulate when the digital input is off.

The following procedures explain how to set up conditional energy for command interface

control and for digital input control. The procedures refer to register numbers and command

codes. For a listing of command codes, see Table C–2 on page 84.

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Appendix C—Using the Command Interface

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Command Interface Control

•

Set Control—To set control of conditional energy to the command interface:

1. Write command code 9020 to register 8000.

2. In register 3227, set bit 6 to 1 (preserve other bits that are ON).

3. Write 1 to register 8001.

4. Write command code 9021 to register 8000.

•

Start— To start conditional energy accumulation, write command code 6321 to register

8000.

Verify Setup—To verify proper setup, read register 1794. The register should read 1,

indicating conditional energy accumulation is ON.

Stop—To stop conditional energy accumulation, write command code 6320 to register

8000.

Clear—To clear all conditional energy registers (1728-1747), write command code

6212 to register 8000.

Digital Input Control

•

Set Control—To configure conditional energy for digital input control:

1. Write command code 9020 to register 8000.

2. In register 3227, set bit 6 to 0 (preserve other bits that are ON).

3. Configure the digital input that will drive conditional energy accumulation. For the

appropriate digital input, write 3 to the Base +9 register.

4. Write 1 to register 8001.

5. Write command code 9021 to register 8000.

•

Clear—To clear all conditional energy registers (1728–1747), write command code

6212 to register 8000.

Verify Setup—To verify proper setup, read register 1794. The register should read 0

when the digital input is off, indicating that conditional energy accumulation is off. The

Incremental Energy

The power meter’s incremental energy feature allows you to define a start time, end time,

and time interval for incremental energy accumulation. At the end of each incremental

energy period, the following information is available:

•

Wh IN during the last completed interval (reg. 1748–1750)

VARh IN during the last completed interval (reg. 1751–1753)

Wh OUT during the last completed interval (reg. 1754–1756)

VARh OUT during the last completed interval (reg. 1757–1759)

VAh during the last completed interval (reg. 1760–1762)

Date/time of the last completed interval (reg. 1763–1765)

Peak kW demand during the last completed interval (reg. 1940)

Date/Time of Peak kW during the last completed interval (reg. 1941–1943)

Peak kVAR demand during the last completed interval (reg. 1945)

Date/Time of Peak kVAR during the last completed interval (reg. 1946–1948)

Peak kVA demand during the last completed interval (reg. 1950)

Date/Time of Peak kVA during the last completed interval (reg. 1951–1953)

The power meter can log the incremental energy data listed above. This logged data

provides all the information needed to analyze energy and power usage against present or

future utility rates. The information is especially useful for comparing different time-of-use

rate structures.

When using the incremental energy feature, remember that peak demands help minimize

the size of the data log in cases of sliding or rolling demand. Shorter incremental energy

periods make it easier to reconstruct a load profile analysis.

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Appendix C—Using the Command Interface

Using Incremental Energy

Incremental energy accumulation begins at the specified start time and ends at the

specified end time. When the start time arrives, a new incremental energy period begins.

The start and end time are specified in minutes from midnight. For example:

Interval: 420 minutes (7 hours)

Start time: 480 minutes (8:00 a.m.)

End time = 1440 minutes (12:00 p.m.)

The first incremental energy calculation will be from 8:00 a.m. to 3:00 p.m. (7 hours) as

illustrated in Figure C–2. The next interval will be from 3:00 p.m. to 10:00 p.m., and the

third interval will be from 10 p.m. to 12:00 p.m. because 12:00 p.m. is the specified end

time. A new interval will begin on the next day at 8:00 a.m. Incremental energy

accumulation will continue in this manner until the configuration is changed or a new

interval is started by a remote master.

Figure C–2: Incremental energy example

End Time

Start Time

1st Interval (7 hours) = 8:00 a.m. to 3:00 p.m

2nd Interval (7 hours) = 3:00 p.m. to 10:00 p.m

3rd Interval (2 hours) = 10:00 p.m. to 12:00 p.m

•

Set up—To set up incremental energy:

1. Write command code 9020 to register 8000.

2. In register 3230, write a start time (in minutes-from-midnight).

3. For example, 8:00 am is 480 minutes.

4. In register 3231, write an end time (in minutes-from-midnight).

5. Write the desired interval length, from 0–1440 minutes, to register 3229.

6. If incremental energy will be controlled from a remote master, such as a

programmable controller, write 0 to the register.

7. Write 1 to register 8001.

8. Write command code 9021 to register 8000.

•

Start—To start a new incremental energy interval from a remote master, write

command code 6910 to register 8000.

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Appendix C—Using the Command Interface

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Setting Up Individual Harmonic Calculations

The PM810 with a PM810LOG can perform up to the 31st harmonic magnitude and angle

calculations for each metered value and for each residual value. The Power Meter can

perform harmonic magnitude and angle calculations for each metered value and for each

residual value. The harmonic magnitude for current and voltage can be formatted as either

a percentage of the fundamental (THD), as a percentage of the rms values (thd), or rms.

The harmonic magnitude and angles are stored in a set of registers: 13,200–14,608. During

the time that the power meter is refreshing harmonic data, the power meter posts a value of

0 in register 3246. When the set of harmonic registers is updated with new data, the power

meter posts a value of 1 in register 3246. The power meter can be configured to hold the

values in these registers for up to 60 metering update cycles once the data processing is

complete.

The power meter has three operating modes for harmonic data processing: disabled,

magnitude only, and magnitude and angles. Because of the extra processing time

necessary to perform these calculations, the factory default operating mode is magnitudes

only.

To configure the harmonic data processing, write to the registers described in Table C–4:

Table C–4: Registers for Harmonic Calculations

Reg No.

Value

Description

Harmonic processing;

0 = disabled

3240

0, 1, 2

1 = magnitudes only enabled

2 = magnitudes and angles enabled

Harmonic magnitude formatting for voltage;

0 = % of fundamental (default)

1 = % of rms

3241

3242

0, 1, 2

2 = rms

Harmonic magnitude formatting for current;

0 = % of fundamental (default)

1 = % of rms

2 = rms

This register shows the harmonics refresh interval

(default is 30 seconds).

3243

3244

10–60 seconds

0–60 seconds

This register shows the time remaining before the

next harmonic data update.

This register indicates whether harmonic data

processing is complete:

3245

0,1

0 = processing incomplete

1 = processing complete

Refer to “Register List Access” on page 79 for instructions on accessing the complete register list.

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Appendix C—Using the Command Interface

Changing Scale Factors

The power meter stores instantaneous metering data in 16-bit single registers. A value held

in each register must be an integer between –32,767 and +32,767. Because some values

for metered current, voltage, and power readings fall outside this range, the power meter

uses multipliers, or scale factors. This enables the power meter to extend the range of

metered values that it can record.

The power meter stores these multipliers as scale factors. A scale factor is the multiplier

expressed as a power of 10. For example, a multiplier of 10 is represented as a scale factor

of 1, since 10 =10; a multiplier of 100 is represented as a scale factor of 2, since 10 =100.

You can change the default value of 1 to other values such as 10, 100, or 1,000. However,

these scale factors are automatically selected when you set up the power meter, either

from the display or by using PowerLogic software.

If the power meter displays “overflow” for any reading, change the scale factor to bring the

reading back into a range that fits in the register. For example, because the register cannot

store a number as large as 138,000, a 138 kV system requires a multiplier of 10. 138,000 is

converted to 13,800 x 10. The power meter stores this value as 13,800 with a scale factor

of 1 (because 10 =10).

Scale factors are arranged in scale groups. You can use the command interface to change

scale factors on a group of metered values. However, be aware of these important points if

you choose to change scale factors:

•

We strongly recommend that you do not change the default scale factors, which are

automatically selected by PowerLogic hardware and software.

•

When using custom software to read power meter data over the communications link,

you must account for these scale factors. To correctly read any metered value with a

scale factor other than 0, multiply the register value read by the appropriate power of 10.

•

As with any change to basic meter setup, when you change a scale factor, all min/max

and peak demand values should be reset.

Enabling Floating-point Registers

For each register in integer format, the power meter includes a duplicate set of registers in

floating-point format. The floating point registers are disabled by default, but they can be

turned ON by doing the following:

NOTE: See “Read and Write Registers” on page 26 for instructions on how to read and

write registers.

1. Read register 11700 (Current Phase A in floating-point format). If floating-point registers

are OFF, you will see -32,768.

2. Write command code 9020 to register 8000.

3. Write 1 to register 3248.

4. Write 1 to register 8001.

5. Write command code 9021 to register 8000.

6. Read register 11700. You will see a value of 1, which indicates floating-point registers

are ON.

NOTE: Values such as current phase A are not shown in floating-point format on the

display even though floating-point registers are ON. To view floating-point values, read the

floating-point registers using the display or PowerLogic software.

Refer to “Register List Access” on page 79 for instructions on accessing the complete register list.

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Appendix C—Using the Command Interface

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Appendix D—Advanced Power Quality Evaluations

The information in this appendix applies to the following models:

•

PM850—EN50160 (evaluation only)

PM870—EN50160, ITI (CBEMA), and SEMI-F47

Power Quality Standards

The Advanced Power Quality feature includes power quality (PQ) evaluations according to

the European standard EN50160 and the SEMI-F47/ITI (CBEMA) specifications. The

PM870 registers data under both standards. The PM850 can report data under the

EN50160 standard only. For instructions on how to enable these evaluation features, see

“PQ Advanced Evaluation Setup” on page 22.

SEMI-F47/ITI (CBEMA) Specification

The SEMI-F47-200 Specification for Semiconductor Processing Equipment Voltage Sag

Immunity was approved by the Global Facilities Committee and is the direct responsibility

of the North American Facilities Committee. This standard is very similar to the Information

Technical Industry (ITI) Council standard.

Semiconductor factories require high levels of power quality due to the sensitivity of

equipment and process controls. Semiconductor processing equipment is especially

vulnerable to voltage sags.

The SEMI-F47 standard addresses specifications for semiconductor processing equipment

voltage sag immunity. It does not include over-voltage conditions, voltage sag durations

less than 0.05 seconds (50 milliseconds), or voltage sag duration greater than 1.0 seconds.

If necessary, the ITI CBEMA-curve can be used to specify additional requirements.

Refer to the Schneider Electric POWERLOGIC Web Pages Instruction Bulletin (document

# 63230-304-207) for more information on using the web pages on the ECC to view

SEMI-47 and ITI(CBEMA) data.

Table D–1: Categorized disturbance levels (% of nominal)

Sag levels

Swell levels

80% — 90%

70% — 80%

40% — 70%

0% — 40%

110% — 120%

120% — 140%

140% — 200%

200% — 500%

Table D–2: Duration categories

Duration

< 20 msec

20 msec — 500 msec

500 msec — 10 sec

>10 sec

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Figure D–1: ITI (CBEMA) Curve

ITI (CBEMA) Curve

500

400

300

Prohibited Region

Voltage Tolerance Envelope

Applicable to 120, 120/208,

and 120/240 Nominal Voltages

200

140

120

100

110

No Interruption In Function Region

No Damage Region

Steady

State

0.5 s

20 ms

10 s

Duration in Seconds (s)

Table D–3: Categorized disturbance levels (F-47)

Sag levels

80% — 90%

70% — 80%

50% — 70%

0% — 50%

Table D–4: Duration categories

Duration

< 50 msec

50 msec — 200 msec

200 msec — 500 msec

500 msec — 1000 msec

>1000 msec

Figure D–2: Voltage Sag ride-through capability

Duration of Voltage Sag in Seconds

0.05

100

0.10

0.20

0.50

1.00

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Appendix D—Advanced Power Quality Evaluations

EN50160:2000 Specification

EN50160:2000 “Voltage characteristics of electricity supplied by public distribution systems”

is a European standard that defines the quality of the voltage a customer can expect from

the electric utility. Although this is a European standard, it can be applied globally.

The PM850 and the PM870 evaluates the following electrical characteristics in accordance

with EN50160:

Table D–5: EN50160 Evaluation for the PM850 and PM870

Feature

PM850

PM870

Evaluation During Normal Operation (Meter-based Data)

Frequency

Supply voltage variations

Supply voltage unbalance

Harmonic voltage

Total Harmonic Distortion

➀

Evaluations During Abnormal Operations (Alarm-based Data)

Magnitude of rapid voltage changes

Supply voltage dips

➁

Short interruptions of the supply voltage

Long interruptions of the supply voltage

Temporary power frequency over-voltages

➁

➀ The PM850 performs EN50160 evaluations based on standard alarms, while the

PM870 performs EN50160 evaluations on disturbance alarms.

➁ These features must be configured using register writes. See Table D–11 on page 99

for a list of configuration and status registers.

As illustrated in Table D–5, the EN50160 evaluations performed by the PM850 and the

PM870 can be divided into two categories. The first category performs evaluations during

normal operation utilizing meter data. The second category performs evaluations during

abnormal operation utilizing either standard alarms (PM850) or disturbance alarms (PM870).

The EN50160:2000 Specification sets limits for most of the evaluations. These limits are

built into the PM850 and the PM870 firmware. You can configure registers for other

evaluations and change them from the default values.

How Evaluation Results Are Reported

The PM850 and the PM870 reports evaluation data in register entries and alarm log

entries. Table D–6 describes the register entries for the evaluation data.

Table D–6: Register Entries

Description

Number

Summary bitmap of active evaluations that reports which areas

of evaluation are active in the PM850 and the PM870.

3910

Summary bitmap of evaluation status that reports the pass/fail

status of each area of evaluation.

3911

Detail bitmap of evaluation status that reports the pass/fail status

of the evaluation of each individual data item. Detailed data

summary information is also available for each of the evaluations

Portal registers

for the present interval and for the previous interval. You can

access this data over a communications link using Modbus block

reads of “portal” registers. Refer to “Evaluation During Normal

Operation” on page 96 for additional information.

Log entries for the evaluation data include:

•

On-board alarm log entry for diagnostic alarms: When the status of an area of

evaluation is outside the range of acceptable values, an entry is made in the on-board

alarm log. This entry provides notification of the exception for a specific area of

evaluation. This notification is reported only in PowerLogic software and does not

appear on the local display.

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•

On-board alarm log entry for alarms: PM850 and the PM870 alarms are used to

perform some of the evaluations. If an on-board alarm log is enabled, an entry will be

made in the on-board alarm log when any of these alarms pick up or drop out.

NOTE: Enabling PQ Advanced evaluation does not guarantee that the on-board alarm log

or waveform files are enabled or properly configured to record these events. You should

consider your requirements and configure these files and the event captures triggered by

the various alarms to provide any additional data that would be helpful to diagnose or

document an exception to this standard.

Possible Configurations Through Register Writes

This section describes the changes you can make to configurations for the EN50160

evaluation through register writes in the PM850 and the PM870. Refer to “Advanced

Power Quality Evaluation System Configuration and Status Registers [EN50160 and

SEMI-F47/ITI (CBEMA)]” on page 99 for register assignments.

•

Select the first day of the week for evaluations. You can define the first day of the

week to be used for the EN50160 evaluations in register 3905.

•

Define the voltage interruption. The standard defines an interruption as voltage less

than 1% of nominal voltage. Because some locations require a different definition, you

can configure this value in register 3906.

•

Define allowable range of slow voltage variations. The standard defines the allowable

range of slow voltage variations to be ±10% of nominal voltage. Because some locations

require a different definition, you can configure this value in register 3907.

Evaluation During Normal Operation

When the EN50160 evaluation is enabled, the PM850 and the PM870 evaluates metered

data under normal operating conditions, “excluding situations arising from faults or voltage

interruptions.” For this evaluation, normal operating conditions are defined as all phase

voltages greater than the definition of interruption. The standard specifies acceptable

ranges of operation for these data items.

This section describes how the EN50160 standard addresses metered data.

Power Frequency

EN50160 states that the nominal frequency of the supply voltage shall be 50 Hz. Under

normal operating conditions, the power meter will perform the valuation based on the

nominal frequency set on the meter.

•

for systems with synchronous connection to an interconnected system:

— 50 Hz 1% during 99.5% of a year

— 50 Hz + 4 to -6% for 100% of the time

•

for systems with no synchronous connection to an interconnected system (for example,

power systems on some islands):

— 50 Hz 2% during 95% of a week

— 50 Hz 15% for 100% of the time

NOTE: The same range of percentages are used for 60 Hz systems.

Supply Voltage Variations

EN50160 states that, under normal operating conditions, excluding situations arising from

faults or voltage interruptions:

•

during each period of one week 95% of the ten minute mean rms values of the supply

voltage shall be within the range of U 10%.

•

all ten minute mean rms values of the supply voltage shall be within the range of U

+10% to -15%.

EN 50160:2000, Voltage characteristics of electricity supplied by public distribution systems.

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Appendix D—Advanced Power Quality Evaluations

Supply Voltage Unbalance

EN50160 states that, under normal operating conditions, during each period of one week,

95% of the ten minute mean rms values of the negative phase sequence component of the

supply voltage shall be within the range 0–2% of the positive phase sequence component.

Harmonic Voltage

EN50160 states that, under normal operating conditions, during each period of one week,

95% of the ten minute mean rms values of each individual harmonic voltage shall be less

than or equal to the value given in Table D–7. Additionally, the THD of the supply voltage

shall be less than 8%.

Table D–7: Values of individual harmonic voltages at the supply terminals for orders up

to 25 in % of nominal voltage

Odd Harmonics

Even Harmonics

Not Multiples of 3

Multiples of 3

Relative

Voltage

Order h

Voltage

1.5%

0.5%

3.5%

6...24

0.5%

1.5%

NOTE: No values are given for harmonics of order higher than 25, as they are usually small, but largely

unpredictable because of resonance effects.

Evaluations During Abnormal Operation

Count of Magnitude of Rapid Voltage Changes

The standard does not specify the rate of change of the voltage for this evaluation. For this

evaluation, the PM850 and the PM870 counts a change of  5% nominal and  10%

nominal from one one-second meter cycle to the next one-second meter cycle. It counts

rapid voltage decreases and increases separately. The interval for accumulation of these

events is one week.

You can configure the number of allowable events per week in register 3917.

(Default = -32768 = Pass/Fail evaluation disabled.)

Detection and Classification of Supply Voltage Dips

According to EN50160, voltage dips are generally caused by faults in installations or the

electrical utility distribution system. The faults are unpredictable and frequency varies

depending on the type of power system and where events are monitored.

Under normal operating conditions, the number of voltage dips expected may be anywhere

from less than a hundred to nearly a thousand. The majority of voltage dips last less than

one second with a depth less than 60%. However, voltage dips of greater depth and

duration can occasionally occur. In some regions, voltage dips with depths between 10%

and 15% of the nominal voltage are common because of the switching of loads at a

customer’s installation.

Supply voltage dips are under-voltage events that last from 10 ms to 1 minute. Magnitudes

are the minimum rms values during the event. Disturbance alarms are used to detect these

events in the PM870. Standard speed under-voltage alarms are used to detect these

events in the PM850. The standard does not specifically address how to classify supply

voltage dips or how many are allowable. Table D–8 shows how the PM850 and the PM870

detect and classify the dips for each phase voltage.

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Table D–8: Voltage dip classifications

Duration (t) seconds

1  t < 3

3  t < 10 10  t < 20 20  t < 60 60  t < 180

Total

Depth (D) % Nominal

10 D < 15

15 D < 30

30 D < 45

45 D < 60

60 D < 75

75 D < 90

90 D < 99

Total

You can configure the number of allowable events per week for each range of Depth in

registers 3920 – 3927. (Default = -32768 = Pass/Fail evaluation disabled.)

Detection of Interruptions of the Supply Voltage

The standard defines an interruption as voltage less than 1% of nominal voltage. Because

some locations require a different definition, you can configure this value in register 3906.

Interruptions are classified as “short” if duration  3 minutes or “long” otherwise. The

PM850 and the PM870 classifies interruptions as shown in Table D–9.

Table D–9: Voltage interruptions

Duration (t) seconds

5  t < 10  t < 20  t < 60  t < 180  t < 600  t <

t < 1

1  t < 2 2 t < 5

1200  t

180

600

1200

Total

You can configure the number of allowable short interruptions per year in register 3918

(Default = -32768 = Pass/Fail evaluation disabled). You can configure the number of

allowable long interruptions per year in register 3919. (Default = -32768 = Pass/Fail

evaluation disabled.)

Detecting and Classifying Temporary Power Frequency Over-voltages

As stated in EN50160, a temporary power frequency over-voltage generally appears during

a fault in the electrical utility power distribution system or in a customer’s installation, and

disappears when the fault is cleared. Usually, the over-voltage may reach the value of

phase-to-phase voltage because of a shift of the neutral point of the three-phase voltage

system.

Under certain circumstances, a fault occurring upstream from a transformer will produce

temporary over-voltages on the low voltage side for the time during which the fault current

flows. Such over-voltages will generally not exceed 1.5 kV rms.

Table D–10 shows how the PM850 and the PM870 detect and classify the over-voltages for

each phase voltage.

NOTE: Disturbance alarms are used to detect these events in the PM870. In the PM850,

standard speed over-voltage alarms are used to detect these events.

Table D–10: Over-voltages

Duration (t) seconds

Magnitude (M) %

1  t < 3 3  t < 10 10  t < 20 20  t < 60 60  t < 180

Total

Nominal

110 < M  115

115 < M  130

130 < M  145

145 < M  160

160 < M  175

175 < M  200

M > 200

Total

You can configure the number of allowable events per week for each range of magnitude in

registers 3930 – 3937. (Default = -32768 = Pass/Fail evaluation disabled.)

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Appendix D—Advanced Power Quality Evaluations

Operation with PQ Advanced Enabled

This section describes how PM850 and PM870 EN50160 evaluation operation is affected

when PQ Advanced evaluation is enabled.

Resetting Statistics

You can reset statistics for the EN50160 evaluations with the command 11100. A

parameter value of 9999 will reset all items. A timestamp is provided in registers for each

item indicating when the last reset was performed. This command is disabled when

revenue security is active.

NOTE: You should reset statistics when you enable EN50160 for the first time and also

whenever you make any changes to the basic meter setup such as changing the nominal

voltage. See “Setting Up PQ Advanced Evaluation from the Display” on page 104.

Harmonic Calculations

When PQ Advanced evaluation is enabled, the harmonic calculations will be set to update

every 10 seconds. You can select the format of the harmonic calculations to be %Nominal,

%Fundamental, or %RMS.

Time Intervals

Time intervals are synchronized with the Trending and Forecasting feature. For additional

information, refer to the Schneider Electric POWERLOGIC Web Pages Instruction Bulletin

(document # 63230-304-207). Weekly values will be posted at midnight of the morning of

the “First Day of Week” configured in register 3905. Yearly values will be based on the

calendar year.

All of the EN50160 data is stored in non-volatile memory once per hour or when an event

occurs. In the event of a meter reset, up to one hour of routine meter evaluation data will be

lost.

Advanced Power Quality Evaluation System Configuration

and Status Registers [EN50160 and SEMI-F47/ITI (CBEMA)]

Table D–11 lists registers for system configuration and status evaluation.

Table D–11: PQ Advanced Evaluation System Configuration and Status Registers

Enable/Disable PQ Advanced Evaluation

3900

3901

3902

3903

3904

0 = Disable (default)

1 = Enable

Nominal Voltage, (copied from register 3234 for reference)

Default = 230

Voltage Selection for 4-Wire Systems

0 = Line-to-Neutral (default)

1 = Line-to-Line

Nominal Frequency, Hz (copied from register 3208 for reference)

Default = 60

Frequency configuration

0 = system with synchronous connection to interconnected system (default)

1 = system without synchronous connection to interconnected system

First Day of Week (EN50160 only)

1 = Sunday

2 = Monday (default)

3 = Tuesday

3905

4 = Wednesday

5 = Thursday

6 = Friday

7 = Saturday

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Appendix D—Advanced Power Quality Evaluations

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Table D–11: PQ Advanced Evaluation System Configuration and Status Registers

Definition of Interruption (EN50160 only)

3906

3907

0 – 10% Nominal (default = 1)

Allowable Range of Slow Voltage Variations (EN50160 only)

1 – 20% Nominal (default = 10)

3908

3909

Reserved

Bitmap of active evaluations

Bit 00 – Summary bit – at least one EN50160 evaluation is active

Bit 01 – Frequency

Bit 02 – Supply voltage variations

Bit 03 – Magnitude of rapid voltage changes

Bit 04 – Not used

Bit 05 – Supply voltage dips

Bit 06 – Short interruptions of the supply voltage

Bit 07 – Long interruptions of the supply voltage

Bit 08 – Temporary power frequency over-voltages

Bit 09 – Not used

3910

Bit 10 – Supply voltage unbalance

Bit 11 – Harmonic voltage

Bit 12 – THD

Bit 13 – Not used

Bit 14 – Not used

Bit 15 – Not used

Bitmap of evaluation status summary

Bit 00 – Summary bit – at least one EN50160 evaluation has failed.

Bit 01 – Frequency

Bit 02 – Supply voltage variations

Bit 03 – Magnitude of rapid voltage changes

Bit 04 – Not used

Bit 05 – Supply voltage dips

Bit 06 – Short interruptions of the supply voltage

Bit 07 – Long interruptions of the supply voltage

Bit 08 – Temporary power frequency over-voltages

Bit 09 – Not used

3911

Bit 10 – Supply voltage unbalance

Bit 11 – Harmonic voltage

Bit 12 – THD

Bit 13 – Not used

Bit 14 – Not used

Bit 15 – Not used

3912

3914

3916

Count of 10-second intervals present year

Count of 10-second intervals this week

Count of 10-minute intervals this week

Number of allowable rapid voltage changes per week

Default = -32768 = Pass/Fail evaluation disabled

Number of allowable short interruptions per year

Default = -32768 = Pass/Fail evaluation disabled

Number of allowable long interruptions per year

Default = -32768 = Pass/Fail evaluation disabled

Number of allowable voltage dips per week for each range of Depth

Default = -32768 = Pass/Fail evaluation disabled

3917

3918

3919

3920

3930

Number of allowable over-voltages per week for each range of Magnitude

Default = -32768 = Pass/Fail evaluation disabled

100

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Appendix D—Advanced Power Quality Evaluations

EN50160 Evaluation Data Available Over a Communications Link

Portal Registers

Evaluation data is available over communications via “portal” register reads. Each data

item is assigned a portal register number. A block read of the specified size at that address

will return the data for that item. In general, if the block size is smaller than specified, the

data returned will be 0x8000 (-32768) to indicate the data is invalid. If the block size is

larger than specified, the data for the item will be returned and the remaining registers will

be padded with 0x8000. Refer to Table D–12 for portal register descriptions.

Table D–12: Portal Register Descriptions

Portal

Description Size

Data

being reported)

Average value (at end of last completed averaging time period)

Minimum value during the last completed averaging time period

Maximum value during the last completed averaging time period

Minimum value during this interval

Maximum value during this interval

Minimum value during the last interval

Maximum value during the last interval

Summary of

53432 –

53434

Meter Data

Evaluations by

Item

Percent in Evaluation Range 1 this interval

Percent in Evaluation Range 2 this interval (when applicable)

Percent in Evaluation Range 1 last interval

Percent in Evaluation Range 2 last interval (when applicable)

Count of average values in Evaluation Range 1 (MOD10L2)

Count of average values in Evaluation Range 2 (MOD10L2)

Count of total valid averages for Evaluation of Range 1 (MOD10L2)

Count of total valid averages for Evaluation of Range 2 (MOD10L2)

Date/Time Last Excursion Range 1 (4-register format)

Date/Time Last Excursion Range 2 (4-register format)

Date/Time Last Reset (4-register format)

Count of rapid voltage increases this week

Count of rapid voltage decreases this week

Summary of

Rapid Voltage

Changes by

Phase

Count of rapid voltage increases last week

53435 –

53437

Count of rapid voltage decreases last week

Date/Time last rapid voltage change (4-register format)

Date/Time last reset (4-register format)

Count of dips by magnitude & duration this week (96 values) [See

“Detection and Classification of Supply Voltage Dips” on page 97.]

Summary of

Voltage Dips

by Phase This

Week

53438 –

53440

104

Date/Time last voltage dip (4-register format)

Date/Time last reset (4-register format)

Count of dips by magnitude & duration last week (96 values) [See

“Detection and Classification of Supply Voltage Dips” on page 97.

Summary of

Voltage Dips

by Phase Last

Week

53441 –

53443

104

Date/Time last voltage dip (4-register format)

Date/Time last reset (4-register format)

Flag indicating interruption is active

Elapsed seconds for interruption in progress

Count of short interruptions this year

Count of long interruption this year

Summary of

Supply

Voltage

Interruptions

3-Phase and

by Phase

Count of short interruptions last year

Count of long interruptions last year

53444 –

53447

Count of interruptions by duration this year (10 values) [See “Detection of

Interruptions of the Supply Voltage” on page 98.]

Count of interruptions by duration last year (10 values) [See “Detection of

Interruptions of the Supply Voltage” on page 98.]

Date/Time of last interruption (4-register format)

Date/Time of last reset (4-register format)

101

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Appendix D—Advanced Power Quality Evaluations

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Table D–12: Portal Register Descriptions

Portal

Description Size

Data

Temporary

Power

Frequency

Over-voltages

by Phase This

Week

Count of over-voltages by magnitude & duration this week (96 values) [See

“Detecting and Classifying Temporary Power Frequency Over-

voltages” on page 98.]

53448 –

53449

104

Date/Time last over-voltage (4-register format)

Date/Time last reset (4-register format)

Temporary

Power

Frequency

Over-voltages

by Phase Last

Week

Count of over-voltages by magnitude & duration last week (96 values) [See

“Detecting and Classifying Temporary Power Frequency Over-

voltages” on page 98.]

53450 –

53452

104

Date/Time last over-voltage (4-register format)

Date/Time last reset (4-register format)

status summary (same as register

evaluations (same as register 3910)

3911)

Bit set when evaluation is active

Bit set when evaluation fails

Bit 00 – Summary bit – at least one

EN50160 evaluation is active

EN50160 evaluation has failed

Bit 01 – Frequency

Bit 02 – Supply voltage variations

Bit 03 – Magnitude of rapid voltage

changes

Bit 04 – Not used

Bit 05 – Supply voltage dips

Evaluation

Summary

Bitmap

Bit 06 – Short interruptions of the

supply voltage

53312

supply voltage

Bit 07 – Long interruptions of the

supply voltage

Bit 08 – Temporary power frequency

over-voltages

Bit 09 – Not used

Bit 10 – Supply voltage unbalance

Bit 11 – Harmonic voltage

Bit 12 – THD

Bit 13 – Not used

Bit 14 – Not used

Bit 15 – Not used

(Range 2) – Bitmap of evaluation

status of individual evaluations

(Range 2) – Bitmap of evaluation

status of individual evaluations

Bit 00 – Frequency

Bit 01 – Va

Bit 00 – Va H7

Bit 01 – Va H8

Bit 02 – Va H9

Bit 03 – Va H10

Bit 04 – Va H11

Bit 05 – Va H12

Bit 06 – Va H13

Bit 07 – Va H14

Bit 08 – Va H15

Bit 09 – Va H16

Bit 10 – Va H17

Bit 11 – Va H18

Bit 12 – Va H19

Bit 13 – Va H20

Bit 14 – Va H21

Bit 15 – Va H22

Bit 02 – Vb

Bit 03 – Vc

Bit 04 – Not used

Bit 05 – Not used

Bit 06 – Not used

Bit 07 – Voltage Unbalance

Bit 08 – THD Va

Bit 09 – THD Vb

Bit 10 – THD Vc

Bit 11 – Va H2

Bit 12 – Va H3

Bit 13 – Va H4

Bit 14 – Va H5

Bit 15 – Va H6

102

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Appendix D—Advanced Power Quality Evaluations

Table D–12: Portal Register Descriptions

Portal Description Size

Data

(Range 2) – Bitmap of evaluation

status of individual evaluations

(Range 2) – Bitmap of evaluation

status of individual evaluations

Bit 00 – Va H23

Bit 01 – Va H24

Bit 02 – Va H25

Bit 03 – Vb H2

Bit 04 – Vb H3

Bit 05 – Vb H4

Bit 06 – Vb H5

Bit 07 – Vb H6

Bit 08 – Vb H7

Bit 09 – Vb H8

Bit 10 – Vb H9

Bit 11 – Vb H10

Bit 12 – Vb H11

Bit 13 – Vb H12

Bit 14 – Vb H13

Bit 15 – Vb H14

Bit 00 – Vb H15

Bit 01 – Vb H16

Bit 02 – Vb H17

Bit 03 – Vb H18

Bit 04 – Vb H19

Bit 05 – Vb H20

Bit 06 – Vb H21

Bit 07 – Vb H22

Bit 08 – Vb H23

Bit 09 – Vb H24

Bit 10 – Vb H25

Bit 11 – Vc H2

Bit 12 – Vc H3

Bit 13 – Vc H4

Bit 14 – Vc H5

Bit 15 – Vc H6

(Range 2) – Bitmap of evaluation

status of individual evaluations

(Range 2) – Bitmap of evaluation

status of individual evaluations

Bit 00 – Vc H7

Bit 01 – Vc H8

Bit 02 – Vc H9

Bit 03 – Vc H10

Bit 04 – Vc H11

Bit 05 – Vc H12

Bit 06 – Vc H13

Bit 07 – Vc H14

Bit 08 – Vc H15

Bit 09 – Vc H16

Bit 10 – Vc H17

Bit 11 – Vc H18

Bit 12 – Vc H19

Bit 13 – Vc H20

Bit 14 – Vc H21

Bit 15 – Vc H22

Bit 00 – Vc H23

Bit 01 – Vc H24

Bit 02 – Vc H25

Bit 03 – V 3PH

Bit 04 – KW 3PH

Bit 05 – KVAR 3PH

Bit 06 – Ia

Bit 07 – Ib

Bit 08 – Ic

Bit 09 – Ia H3

Bit 10 – Ib H3

Bit 11 – Ic H3

Bit 12 – Ia H5

Bit 13 – Ib H5

Bit 14 – Ic H5

Bit 15 – Ia H7

(Range 2) – Bitmap of evaluation

status of individual evaluations

(Range 2) – Bitmap of evaluation

status of individual evaluations

Bit 00 – Ib H7

Bit 00 – Reserved

Bit 01 – Reserved

Bit 02 – Reserved

Bit 03 – Reserved

Bit 04 – Reserved

Bit 05 – Reserved

Bit 06 – Reserved

Bit 07 – Reserved

Bit 08 – Not used

Bit 09 – Not used

Bit 10 – Not used

Bit 11 – Not used

Bit 12 – Not used

Bit 13 – Not used

Bit 14 – Not used

Bit 15 – Not used

Bit 01 – Ic H7

Bit 02 – Ia H9

Bit 03 – Ib H9

Bit 04 – Ic H9

Bit 05 – Ia H11

Bit 06 – Ib H11

Bit 07 – Ic H11

Bit 08 – Ia H13

Bit 09 – Ib H13

Bit 10 – Ic H13

Bit 11 – Reserved

Bit 12 – Reserved

Bit 13 – Reserved

Bit 14 – Reserved

Bit 15 – Reserved

103

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Appendix D—Advanced Power Quality Evaluations

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Alarms Allocated for PQ Advanced Evaluations

To accomplish some of the evaluations required and to provide a record of events in the

on-board alarm log, the PM850 uses standard alarms, and the PM870 uses disturbance

alarms. When the evaluation is enabled, certain alarm positions will be claimed and

automatically configured for use in the evaluation. You cannot use these alarms for other

purposes while the evaluation is enabled. These alarms include:

•

Over Voltage (PM850): Standard speed alarm positions 35-37

Under Voltage (PM850): Standard speed alarm positions 38-40

Disturbance for Voltage Swells and Sags (PM870): Disturbance alarm positions 1-3 and 7-9

NOTE: The position depends on the system type (register 3902).

“PQ Advanced” is included in the alarm label for alarms being used by this evaluation.

Setting Up PQ Advanced Evaluation from the Display

To set up the PQ Advanced evaluation in the power meter, you need to perform these

steps using the meter set-up procedure:

1. Enable the PQ Advanced evaluation.

By default, the PQ Advanced evaluation is disabled. To enable the evaluation, use the

display (see “PQ Advanced Evaluation Setup” on page 22).

2. Select the nominal voltage of your system.

NOTE: The EN50160 standard defines nominal voltage for low-voltage systems to be

230V line-to-line for 3-wire systems or 230V line-to-neutral for 4-wire systems.

Therefore, the default value for Nominal Voltage is 230.

If the application is a medium-voltage system, or if you want the evaluations to be

based on some other nominal voltage, you can configure this value using the display

only. PowerLogic software does not allow configuration of nominal voltage

3. Select the nominal frequency of your system.

NOTE: The EN50160 standard defines nominal frequency as 50 Hz, but the PM850 and

the PM870 can also evaluate 60 Hz systems. They cannot evaluate nominal frequency

for 400 Hz systems.

The default nominal frequency in the PM850 and the PM870 is 60 Hz. To change the

default, from the display Main Menu, select Setup > Meter > Frequency. From

PowerLogic software, see the online help file.

4. Reset the PQ Advanced Statistics.

a. Write 9999 in register 8001.

b. Write 11100 in register 8000.

Refer to “Resetting Statistics” on page 99.

5. Reset the ITI (CBEMA) and SEMI F-47 Statistics.

a. Write 9999 in register 8001.

b. Write 11200 in register 8000.

Refer to “Resetting Statistics” on page 99.

104

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Glossary

Terms

accumulated energy—energy can

event—the occurrence of an alarm

accumulate in either signed or unsigned condition, such as Under-voltage Phase

(absolute) mode. In signed mode, the

direction of power flow is considered,

and the accumulated energy magnitude

may increase and decrease. In absolute

mode, energy accumulates as a

positive, regardless of the power flow

direction.

A, configured in the power meter.

firmware—operating system within the

power meter.

fixed block—an interval selected from

1 to 60 minutes (in 1-minute

increments). The power meter

calculates and updates the demand at

the end of each interval.

active alarm—an alarm that has been

set up to trigger, when certain

conditions are met, the execution of a

task or notification. An icon in the

upper-right corner of the meter

indicates that an alarm is active (!).