Power Monitoring and Control Systems Catalogstevenengineering.com/Tech_Support/PDFs/45PWRLOG.pdfPower Monitoring and Control Systems Introduction Improve power quality Power quality

Power Monitoring andControl SystemsCatalog

Class 3000

Table of Contents

Power Monitoring and Control Systems Introduction .................. Page 4

Power Meters .............................................................................. Page 8

Circuit Monitors ........................................................................... Page 12

System Manager™ 3000 Software ............................................. Page 18

Ethernet Gateway ....................................................................... Page 24

Digital Relay ................................................................................ Page 28

MICROLOGIC® Circuit Breaker Interface .................................... Page 34

LIFE-GARD® Model 85A Temperature Controller Interface ......... Page 36

Power Management Services ..................................................... Page 38

Year 2000 Compliance ................................................................ Page 42

Suggested System Specifications ............................................... Page 43

Glossary of Terms ....................................................................... Page 68

4

POWER MONITORING & CONTROL SYSTEMS

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Power Monitor ing and ControlSystems Introduct ion

Profitability with power monitoringIf you knew where and how to cut peak demand power usage, you couldlower your electric bills and your company’s cost of product. But how canyou, when you have no idea how your demand patterns relate to produc-tion?

Perhaps you would like to stretch this year’s budget by deferring thepurchase of a new substation, but you are not sure you have enoughcapacity to accommodate the vital new process equipment you need toinstall. Take a chance and the whole line could go down–at who knowswhat cost in downtime. If you only knew where and how much excesscapacity you have.

Electric utility deregulationis changing the way youbuy electricity. But do youknow all you need to knowabout your electricalneeds, including thequality of power needed,in addition to knowingwhen and how muchpower is needed?

Electricity–once consid-ered an uncontrollablecost of doing business–isbrought under controlthrough power monitoringand control systems. Witha power monitoring and control system, a facility engineer has the ability tolocate trouble spots and prevent outages or downtime, as well as deter-mine energy use by department or product line.

The POWERLOGIC Power Monitoring and Control System from Square Dis an innovative total system solution to managing electricity and improvingthe reliability of power distribution equipment. The POWERLOGIC systemcombines microprocessor-based instrumentation and control to provideadvanced features for industrial, commercial and utility electrical systems.The POWERLOGIC system’s exceptionally accurate instruments, high-speed communications network, and fully integrated power monitoringapplication software make these benefits possible.

Controlling costs to maximize profitsOne of the keys to maximizing profit is by controlling costs. A powermonitoring system helps you do that in two ways. It allows you to betterknow the impact electrical costs have on your operating costs, and givesyou the information you need to purchase electricity more cost effectively.

Reduction of downtimeMinimizing downtime is critical to the profitability every operation. Unex-pected power outages and having key pieces of equipment shut downsuddenly is expensive due to the time required to find the source of theproblem, correct it, and get production started again. The loss of productadds additional expense. The key is to identify potential problems andcorrect them proactively. For example, the current on a critical motor mayhave become higher than normal. A bearing may be failing. The powermonitoring system’s overload alarm alerts the operator of the situation sothe problem can be identified and corrected with a minimum of downtime.

The POWERLOGIC system provides the informationyou need to control utility costs and, perhaps moreimportant, downtime costs.

From the personal computer on your desk, you can runthe world’s most powerful monitoring and control system:the POWERLOGIC system.

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Power Monitor ing and Contro lSystems Introduct ion

Improve power qualityPower quality concerns include making sure the power delivered to criticalmachines and processes is both clean and dependable. Computers andmicroprocessor-based control systems are very sensitive to the quality ofpower they use. The first step to solving power quality problems is todetermine the magnitude of the problem. This is one of the functions of thepower monitoring system.

Lower energy costsThe power monitoring system can help lower energy costs in several ways.First, demand charges can often be reduced through the analysis ofmaximum and minimum readings and reviewing time and trend plots ofdata logs. Alarms can be triggered to warn when the system is in danger ofcreating new peaks. Second, power factor penalties can be reduced byusing power factor correction capacitors (PFCs). But to use PFCs correctly,you need to know what your power factor is and the harmonic content ofthe circuit. The power monitoring system can be used to determine whenand where capacitors should be used. Finally, the POWERLOGIC systemprovides you with the information about yourpower requirements so you can take full advan-tage of the electrical utitlity deregulation opportu-nities.

Allocate energy costsMore and more companies want to know not onlyhow much energy they are using, but where theyare using it. Competitive pressures necessitateknowing all the costs associated with a product,including the cost of power to produce it. Inaddition, efforts to closely manage energy costsare easier to evaluate when the costs are brokendown by area. The POWERLOGIC system cancreate the trend plots and reports allocating theenergy costs the way you need them.

Better utilization of power distributionequipmentA common question asked is “Does the existingdistribution equipment have enough capacity?” Apower monitoring system with thePOWERLOGIC software displays the data logsin the form of time trend plots. Peak informationfrom date and time stamps of maximum readingsis also useful. This shows which distributionequipment is under utilized, or near overload. Allthis information can be used to obtain themaximum use of existing equipment, and tomore accurately design future distributionequipment.

Special monitoring and control systemsPower monitoring is often just part of thesolution. Monitoring other utilities such as gas,water, and steam may be needed. Sequence ofevents monitoring can be critical. Monitoring andcontrol of generators and transfer switches maybe required. Automatic control systems for Typical POWERLOGIC power monitoring and control system.

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Power Monitor ing and ControlSystems Introduct ion

shedding and restoring loads may be key to minimizing energy costs ormaintaining critical circuits. There are POWERLOGIC solutions for all thesesystems.

How do power monitoring and control systems work?Power monitoring systems monitor the flow of electrical power in circuitsthroughout the plant. In the POWERLOGIC system, highly accurate circuitmonitors and power meters are dedicated to power monitoring, while othercompatible devices collect additional equipment information from protectiverelays, circuit breakers, transformer temperature controllers, andpanelboards.

Electrical data–such as current, power, energy, waveforms, and equipmentstatus–is passed over a data network to one or more personal computers.The personal computers run power monitoring application software thatretrieves, stores, organizes, and displays real-time circuit information insimple, usable formats.

The information collected and stored in a power monitoring system helpsoperate a facility more efficiently. Of course, the quality of the data dependson the accuracy of the instrumentation and the usability of the displayformats. A POWERLOGIC system provides this accuracy in a format that iseasy to use and understand.

Accurate monitoring devicesEach POWERLOGIC monitoring device is a multi-function, digitalinstrumentation, data acquisition device capable of replacing a variety ofmeters, relays, transducers, and other components.

POWERLOGIC system devices can be integrated with Square D’selectrical power distribution products or retrofit into existing equipment. Theresult is a distributed network of intelligent, accurate monitoring devicesreporting to one or more centralized locations.

Flexible connectivity and network topologiesAll POWERLOGIC-compatible devices are equipped with an RS-485network communication port for integration into a POWERLOGIC powermonitoring and control system. Up to 32 devices can be daisy-chained anddirectly connected to a personal computer, system display, Ethernet

gateway (TCP/IP and OSI), or POWERLOGIC networkinterface module (PNIM). Square D can provideindustrially hardened local area networks, or connect toexisting networks, either local or wide area. Othercommunication options such as fiber optics andmodems, including telephone and radio, are alsoavailable. The POWERLOGIC system makes it easy toallow localized, distributed, remote, and any mixednetwork combination.

Powerful software solutionsThe POWERLOGIC application software series offers avariety of power monitoring solutions, allowing you tomonitor, display, and store vast amounts of informationfrom all of the POWERLOGIC compatible devices.

Organized and usable informationThe POWERLOGIC application software seriesautomatically integrates real-time circuit information intoorganized and usable formats. Without any custom

No other monitor gives you more standard communications capabilitiesthan the POWERLOGIC circuit monitor. And once the data gets to yourcomputer, there’s no better way to make sure of all the information thanSystem Manager™ 3000 software.

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Power Monitor ing and Contro lSystems Introduct ion

programming and very minimal setup, the user can readily access real-timeand historical data, time trend plots, alarms, waveform plots, power qualityinformation, data logging, output control, and more.

Evaluation, engineering, and supportSquare D’s Power Management Organization is more than powermonitoring devices and software. It includes highly trained and capableengineers evaluating and providing solutions to power quality issues. Toensure smooth installation and system commissioning, our applicationengineering services are available to oversee the project from design tocompletion. The POWERLOGIC University provides users with the trainingneeded to get the most out of their system. And finally, the TechnicalSupport Group provides the answers to the questions to ensure smoothoperation of your power monitoring system.

Information is powerIf you can’t measure it, you can’t control it. And controlling costs is critical.POWERLOGIC power monitoring systems provide you with the informationyou need to make the sound business decisions needed in today’smarketplace.

See all those meters? A single POWERLOGIC power meter or circuit monitor can do their work and that of many others.Yet it costs less than what you’d pay for just a few of them.

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Power Meters

Economical MeteringSolution

• A single, economicaldevice that replaces afull complement ofanalog meters

• Accurate true RMSmetering of distortedcurrents and voltagesup to the 31stharmonic

• THD readings for eachmetered phase ofcurrent and voltage toassist in measurementof power quality data

• Neutral currentmonitoring to detectoverload neutrals

• Individual machineload monitoring

• Available feedercapacity monitoring(peak demand current)

• Load monitoring forpredictive mainte-nance/troubleshooting

• Remote meter readingand data logging froma personal computerusing POWERLOGICSystem Managersoftware and RS-485communications

Ease of Installation

• Display mounts inpanel cutout ofstandard 1% analogmeters

• Separate meter anddisplay modules allowsflexible mountingoptions

• Easy retrofit intoexisting powerequipment

Direct Connect Up to600 V

• No PTs required up to600 V

• No separate controlpower required on upto 600 V circuits

CommunicationsOptions

• POWERLOGICcommunications forintegration with aPOWERLOGIC powermonitoring system

• Modbus RTUcommunication forintegration with othersystems

• KYZ pulse initiator forcommunication toenergy managementsystems

Features

The POWERLOGIC

Power Meter is

capable of replacing a

full complement of

basic analog meters.

This cost effective,

high performance

meter can operate as

a stand-alone device

or as part of a

POWERLOGIC Power

Monitoring System to

help reduce energy

and maintenance

costs by providing

valuable power

information.

2-Line LCD Display

• Mounts back-to-backor up to 50 feet frompower meter module

• Use as a portablepower meter program-mer

• Provides setup anddisplay of meteringinformation

• Provides opticalisolation from 600 Vmetering connection

Designed for Reliability

• Tested for compliancewith UL and CSArequirements

• FCC compliant(Class A)

• CE marking

• Vibration andtemperature tested

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Power Meters

Basic Metering Solution and MoreThe POWERLOGIC Power Meter is designed for use in basic powermetering applications. It can replace conventional metering devices suchas ammeters, voltmeters, and watt-hour meters while providing powerfulcapabilities not offered by analog metering. The power meter’s true rmsreadings (31st harmonic response) accurately reflect non-linear circuitloading more than conventional analog metering devices. The power metercalculates the neutral current, which can assist in identifying overloadedneutrals due to either unbalanced single phase loads or triplen harmonics.Circuits can be closely monitored for available capacity by keeping track ofthe peak average demand current. Accurate circuit loading information isessential to get the most out of existing power equipment while maintainingpower system reliability.

The power meter provides a full complement of accurate true rms meteringvalues through the optional display, or via the standard RS-485 communi-cation port to a POWERLOGIC Power Monitoring and Control System. Amodel PM-600 power meter module replaces a full complement of basicanalog meters including a watt-hour meter. The model PM-620 powermeter module extends the metering capabilities to report power and currentreadings including the date and time of occurrence. The model PM-620also provides neutral current and per phase THD for each metered currentand voltage. Refer to the tables for information about the metering valuesreported by each model. A KYZ output is included to communicate energyand demand information to third party energy management systems.

Mounting FlexibilityThe power meter’s small size and variety of mounting configurations allowit to be readily installed in new equipment or retrofit into existing equipment.The power meter module can be mounted onto a35mm DIN rail, or it can be mounted on any flatsurface using its four mounting feet. For addedsimplicity in retrofit installations, the panelmounting hole patterns for both the power metermodule and the optional power meter displaymatch the conventional 4-inch ammeter/voltme-ter spacing so the meter and the display can bemounted back-to-back on opposite sides of apanel surface. In metering installations of 600 Vand below, the power meter provides additionalsavings in both cost and mounting space by eliminating the need for PTsand control power transformers.

Versatile DisplayThe optional power meter display mounts in the same space as a conven-

tional 4-inch ammeter and is connected to the powermeter module with a communication cable. With the2-line by 16-character LCD display, the user canview metering data, and access the passwordprotected meter setup and resets menus. Since thepower meter display can be mounted up to 50 feetaway from the power meter module, power meteringcan now be installed in tight equipment spaces

without sacrificing convenient and affordable local display. The communi-cations port on the power meter display is optically isolated from the 600 Vmetering connections.

Power Meter Display

Power Meter Module

POWERLOGIC Power Meter Feature Comparison

Current, per phase A, B, C ● ●

Current, neutral N ●

Volts, L-L A-B, C-B, C-A ● ●

Volts, L-N A-N, B-N, C-N ● ●

Real power (kW) A, B, C, total ● ●

Reactive power (kVAR) A, B, C, total ● ●

Apparent power (kVA) A, B, C, total ● ●

Power factor (true) A, B, C, total ● ●

Frequency ● ●

Current demand A, B, C, N, present & peak ●

Real power demand (kWd) 3 phase total, present & peak ●

Reactive power demand (kVARd) 3 phase total, present & peak ●

Apparent power demand (kVAd) 3 phase total, present & peak ●

Real energy (kWh) 3 phase total ● ●

Reactive energy (kVARh) 3 phase total ● ●

Apparent energy (kVAh) 3 phase total ● ●

Energy accumulation modes Signed, absolute, energy in,energy out ● ●

KYZ output ● ●

RS-485 POWERLOGIC andModbus RTU communications ● ●

Date/time stamping Peak demands, power up/restart,resets ●

THD, voltage & current A, B, C ●

Meter Feature Values ModelPM-600

ModelPM-620

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Powerful FunctionalityThe power meter accepts inputs from standard 5 A CTs and has full scaleinput of 10 A. The voltage inputs can be directly connected to 3 phasecircuits of 600 V and below without the need for PTs or CTs. For highervoltage circuits, the power meter accepts a full range of PT primary valueswith control power derived from the PTs or from a separate source of ac ordc control power. Setup and resets are password protected and are easilydone through the power meter display or via the network using SystemManager™ software, releases SMS-3000, SMS-1500, and PMX-1500.From the optional display, POWERLOGIC or Modbus RTU protocols canbe selected. No DIP switches or other hardware adjustments are requiredfor setup. All readings are scaled to their actual values without the need fora multipler.

POWERLOGIC System CompatibilityThe power meter supports standard POWERLOGIC RS-485 communica-tions up to 19,200 Baud with communications links up to 10,000 feet. Ameter can quickly be installed into any existing POWERLOGIC system.The power meter has been fully integrated into the latest POWERLOGICapplication software, System Manager software, releases SMS-3000,SMS-1500, and PMX-1500. This software enables users to manage theirelectrical distribution systems by providing tabular and graphical datadisplays, alarms, real time and historical time trend tables and graphs, andreports. Power meter setup and reset operations and wiring diagnosticscan also be performed from a remote personal computer using the soft-ware.

POWERLOGIC power monitoring devices and systems assist in equipmentmonitoring for cost allocation, troubleshooting, predictive maintenance,planning, and more. The lower installed cost of the power meter makes itpossible for facilities to monitor many smaller, less critical feeder circuitsenabling whole facility power monitoring.

Power Meters

1

3

4

Power MeterDisplay

(PMD-32)

Power MeterModule

(PM-600 or PM-620)

Power Meter Module and Display Features

2-line x 16 character LCD display

Tactile function keys

Multi-conductor communication cable (up to 50 feet)

Control power, metering KYZ and communications connections

Panel or DIN rail mounting

Removable terminal shield

2

5

6

1

3

4

2

5

6

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Power Meters

Technical SpecificationsMetering SpecificationsCurrent Inputs

Current Range ................ 0–10A acNominal Current .............. 5 A acOvercurrent Withstand .... 500 A, 1 secondBurden ............................ 0.15 VA

Voltage InputsVoltage Range ................ 20–600 V acNominal Voltage .............. 208/120, 480/

277, 600/347 Vrms

Input Impedance ............. >2 MegohmsFrequency Range

(50/60 Hz) ....................... 45–65 HzAccuracy

Current ............................ 0.25%Voltage ............................ 0.25%Power .............................. 0.50%Energy ............................ 0.50%Demand .......................... 0.50%Power Factor ................... 1.00%Frequency 50/60 Hz........ 0.1 Hz

Control Power Input SpecificationsInput Range, ac ................. 90–600 V acFrequency Range .............. 45–65 HzInput Range, dc ................. 100–300 V dcBurden ............................... 5 VA Nominal

Temperature SpecificationsMeter Module (operating) .. 0 to 60°CMeter Display (operating) .. 0 to 55°C

6.03153

4.62117

3.8196.7

4.50114

3.6392.1

1.2632.0

4.50114

4.50114

INCHESMILLIMETERS

Ordering InformationClass Type Description

3020 PM600 Power Meter Module, BasicInstrumentation

3020 PM620 Power Meter Module, BasicInstrumentation, plus Demand,THD, D/T Stamping, NeutralCurrent

3020 PMD32 Power Meter Display with 1 FootCable

3020 SC104 Optional 4 Foot Cable



* 3-Phase, 4-Wire WYE. (3-Wire Delta and other system types supported.)

Typical Wiring Diagram*

Dimensions

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Circui t Monitors

Features

• True rms metering(31st harmonic)

• Accepts standard CTand PT inputs

• High accuracy—0.2%current and voltage

• Over 50 displayedmeter values

• Min/max displays formetered data

• Power quality readings—THD, k-factor, crestfactor

• Harmonic magnitudesand angles through the31st harmonic

• Current and voltagesag/swell detectionand recording

• On-board clock/calendar

• Easy front panel setup(password protected)

• RS-485 communica-tions standard

• Front panel, RS-232optical communica-tions port standard

• Modular, fieldinstallable analog anddigital I/O

• 1 ms time stamping ofstatus inputs forsequence-of-eventsrecording

• I/O modules supportconfigurable KYZpulse output

• Setpoint controlledalarm/relay functions

• On-board event anddata logging

• Waveform and eventcaptures, user-selectable for 4, 12,24, 36, 48 or 60 cycles

• High-speed, triggeredevent capture

• Programminglanguage for applica-tion specific solutions

• Downloadablefirmware

• System connections– 3-phase, 3-wire delta– 3-phase, 4-wire wye– Metered or calcu-lated neutral– Other meteringconnections

• Optional voltage/powermodule for directconnection to 480 Y/277 V

• Optional 18–60 Vdccontrol power

• Wide operatingtemperature range(–25 to 70° C)

• UL Listed and CSACertified, CE marking

The POWERLOGIC

Circuit Monitor is a

multi-function, digital

instrumentation, data

acquisition and control

device capable of

replacing a variety of

meters, relays,

transducers and other

components.

System Highlights

• Supports multiple PCs

• Powerful softwaresolutions

• Easily retrofit

• 500K Baud, highspeed network

• Programmablecontroller support

• Fiber-optic, radio, andmodem communica-tions

• Ethernet interfaces

• Building automationsystem compatible

• MV-90™ billingcompatible

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Ci rcui t Moni tors

Comprehensive MeteringThe POWERLOGIC Circuit Monitor installs on a 3-phase circuit like aconventional watthour meter, but it delivers far more information. In fact,the circuit monitor can replace more than 100 conventional indicatingmeters. All circuit monitors perform highly accurate, true rms metering. TheCM-2050 offers comprehensive metering with 1% accuracy on current andvoltage. Models CM-2150 and higher provide 0.2% accuracy on currentand voltage, and 0.4% accuracy on power and energy.

Protective FunctionsA circuit monitor equipped with an I/O module can perform certain motorprotective functions. These include phase loss, phase reversal, undervoltage, and more. Once the circuit monitor detects the abnormal condition,the output relay switches within 1–3 seconds. Each protective function canoperate one or more form-C, 10 ampere relays. Each relay can be acti-vated by multiple protective functions. These functions are passwordprotected.

Power Quality ReadingsTotal Harmonic Distortion (THD) for current, voltage, and k-factor readingsindicate potential power quality problems which, unchecked, could disruptcritical processes or damage equipment.

Programming CapabilitiesThe CM-2450 Circuit Monitor is programmed using simple math functions,timers, and compare statements to customize data logging, controlfunctions, and more. For example, you could write a program that logs databy exception rather than at regular intervals, thus maximizing the circuitmonitor’s memory. Meter values can be analyzed in the circuit monitor andsummarized in daily, weekly, and monthly reports.

Easy SetupBasic circuit monitor setup can be performed from either the front of thecircuit monitor, or a personal computer running POWERLOGIC applicationsoftware. The PC connects to the circuit monitor using either the systemnetwork or an optical communications interface. No thumbwheel or DIPswitches are involved; therefore, after installation, setup parameters suchas the unit address, CT ratio, PT ratio, and baud rate can be configuredwithout exposing personnel to live conductors. For security, all setupinformation is password protected.

Flexible CommunicationsOptically isolated RS-485 communications connect a network of circuitmonitors into a power monitoring and control system. The industriallyhardened network communicates at speeds up to 500K Baud. It allows avirtually unlimited number of devices to communicate, including circuitmonitors, multiple personal computers, POWERLOGIC trip units for lowvoltage power circuit breakers, MICROLOGIC® solid state circuit breakers,and other compatible devices.

Extended Memory OptionsCircuit monitors provide different amounts of non-volatile memory. Forexample, the CM-2452 can store more than 180,000 values, includingdates and times. The memory can be allocated among an event log, awaveform capture log, an event capture log, and up to 14 data logs. Thetable on the bottom of page 14 shows a typical example of how the user

Real-Time Readings• Current (per phase, N, G, 3Ø)• Voltage (L-L, L-N)• Real Power (per phase, 3Ø)• Reactive Power (per phase, 3Ø)• Apparent Power (per phase, 3Ø)• Power Factor (per phase, 3Ø)• Frequency• Temperature (internal ambient)*• THD (current and voltage)• K-Factor (per phase)

Demand Readings• Demand Current (per-phase, present, peak)• Average Power Factor (3Ø total)• Demand Real Power (3Ø total)• Demand Reactive Power (3Ø total)*• Demand Apparent Power (3Ø total)• Coincident Readings*• Predicted Demands*

Energy Readings• Accumulated Energy, Real• Accumulated Energy, Reactive• Accumulated Energy, Apparent*• Bi-directional Readings*

Power Analysis Values*• Crest Factor (per phase)• K-Factor Demand (per phase)• Displacement Power Factor (per phase, 3Ø)• Fundamental Voltages (per phase)• Fundamental Currents (per phase)• Fundamental Real Power (per phase)• Fundamental Reactive Power (per phase)• Harmonic Power• Unbalance (current and voltage)• Phase Rotation

* Available via communications only.

Instrumentation Summary

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might configure the available memory for various models.

Alarm/Relay FunctionsCircuit monitors can detect over 100 alarm situations, including over/underconditions, status input changes, and phase unbalance conditions. Eachalarm condition can be set to automatically operate one or more circuitmonitor relays. Multiple alarms can be assigned to each relay. Up to threeform-C, 10 A mechanical relays and one solid-state output are available.

On-Board Alarm/Event LoggingWhen an alarm occurs, the circuit monitor can log the event type, date andtime, and the most extreme reading during the pick-up delay. When thealarm condition drops out, the dropout date/time and the most extremereading during the entire event will be logged. The size of the event log canbe user configured.

Data LoggingCircuit monitors are available with non-volatile memory for storing meterread-ings at regular intervals. A user can configure the size and structure ofup to 14 independent data logs to record metered data at intervals from 1minute to 24 hours. Each data log entry can contain up to 100 values(including date/time). Models CM-2150 and -2250 store up to 5,632 values.Models CM-2350 and -2450 store up to 51,200 values. Model CM-2452stores over 180,000 values.

Downloadable FirmwareThe circuit monitor is designed to take advantage of technological ad-vances. As Square D introduces more powerful versions of each circuitmonitor, upgrade kits allow the user to install the new capabilities withoutchanging wiring or hardware. This is possible because the circuit monitorhas downloadable firmware. The new firmware is transmitted from a PCinto the circuit monitor, using the front optical communications port or therear RS-485 port. The equipment containing the monitor does not have tobe de-energized. This allows you to keep your circuit monitors up to datewith the latest enhancements, minimizing the fear of obsolescence.

Field Installable I/O ModulesField installable input/output modules provide maximum flexibility, whilekeeping the costs for an application at a minimum. An I/O module can beeasily installed on the back of the circuit monitor. Seven different I/Omodules are available. The modules provide various combinations of digitaland analog I/O, ranging from 1 digital input and 1 digital output to 4 digital

Circui t Monitors

2

6

5

7

89

10

1

3

4

More than 50 metered values plus extensiveminimum and maximum data can be viewed fromthe large 6-digit LED display.

Six-digit LED display

Kilo/mega units LEDs

Meter indication LEDs

Setup/reset parameters

Phase indication LEDs

Phase select button

Select meter buttons

Mode indication LEDs

Mode select button

Optical communications port

1

3

4

10

2

5

6

7

8

9

Front Panel Features

CM-2050 CM-2150 CM-2250 CM-2350/2450 CM-2452Event Log N/A 200 Events 200 Events 500 Events 1500 Events1 Data Log N/A 8 Days 8 Days 40 Days 120 DaysWaveform Captures➁ N/A N/A 1 3➂ 9

Event Captures➁ N/A N/A 1 3➂ 13√➀ The relative size of log files is user-defined. This table illustrates a typical memory configuration with one data log

that stores the following data hourly: 3Ø avg. amps, volts (L-L, L-N), PF, kW, kVAR, freq., 3Ø demand for amps, kW,kVA, and kWH and kVARH.

➁ Waveform & event captures are stored in non-volatile memory in the CM-2350 and CM-2450. The exact number ofwaveforms and event captures that can be stored depends on how much memory is allocated to event & data logs.

➂ Up to 20 waveform captures or 8 12-cycle event captures can be stored in the CM-2350 and -2450, depending onmemory allocation.

√ The CM-2452 can store up to 60 waveform captures, or 28 12-cycle event captures can be stored in the CM-2350and -2450, depending on memory allocation.

Typical Memory Configuration ➀

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inputs, 4 digital outputs, 4 analog inputs, and 4 analog outputs.

Two inputs and one output perform special functions. Status input S1 canbe configured to accept a demand synch pulse from a utility demand meter.Status input S2 is a high-speed input; it can be connected to an externalrelay to trigger the circuit monitor’s event capture. The KYZ solid-stateoutput is ideal for pulse initiator applications. The form C, 10 amp me-chanical relay outputs are extremely flexible—each can be configured forremote (external) or circuit monitor (internal) control. In addition, eachoutput can be configured for normal, latched, timed, or one of six differentpulse initiator modes. The analog inputs are field convertible from 0–5 Vdcto 4–20 mA.

Waveform CaptureSquare D pioneered the concept of “waveform capture.” Circuit monitorsuse a patented, high-speed sampling technique to sample 64 times per

cycle on all current andvoltage signals simulta-neously. The capturedwaveforms are stored inthe circuit monitormemory for retrievaland display by POW-ERLOGIC applicationsoftware. Waveformcaptures are triggeredinternally or externally.A personal computercan send a signal overthe communicationsnetwork or through theoptical communicationsport. An external signal,for example, from anovercurrent relay, can

be received through a high-speed input. The waveform capture can also betriggered internally by any of over 100 user-defined alarm conditions,including high or low power factor, %THD, or phase loss.

Sag/Swell DetectionThe circuit monitor can continuously monitor for sags and swells on anymetered voltage or current. This feature can help detect and analyzetroublesome voltage disturbances that can cause costly equipment downtime. The circuit monitor detects sags and swells based on user-definedsetpoints and delays (in cycles). When the circuit monitor detects a voltageor current disturbance, it performs an event capture to record the distur-bance. This capture is configurable for 12, 24, 36, 48, or 60 cycles. It isperformed using the same patented, 64 samples-per-cycle sampling rateas the waveform capture. The user selects the number of pre-event cycles,ranging from 2 to 10 cycles. Thus, the event capture shows the circuit bothbefore and after the disturbance. The event can be date and time stampedto the millisecond, and recorded in the event log.

Mounting OptionsIn addition to the standard flush mounting, several other mounting optionsare available. For applications requiring an indoor general purpose surfacemounted (NEMA 1) enclosure, a 3090 SMA-220 is used. The circuit

Ci rcui t Moni tors

POWERLOGIC software can show all phase voltageand current waveforms simultaneously, or a singlewaveform with a data block containing harmonicsthrough the 31st.

POWERLOGIC software can display sag/swell datacaptured by the circuit monitor. This screen showsa voltage sag experienced from a single-phaseoperation of a recloser.

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monitor mounts through the door of the enclosure, providing easy accessto the rear of the monitor. The enclosure is deep enough to accommodate

options, including I/Omodules and voltagepower modules.

For applications wheredepth in the equipmentenclosure is critical,POWERLOGIC providesthe 3090 CMA-100 and3090 CMA-110 adapters.The CMA-100 reducesthe depth requirements byextending the circuit

monitor beyond the front of the equipment. The CMA110 allows thevoltage/power module and some I/O modules to be mounted off of the backof the circuit monitor.

Control Power OptionsIn addition to CT and PT inputs, the circuit monitor requires control power.The circuit monitor accepts a wide range of voltages including 120/240 Vacnominal or 125/250 Vdc nominal. When the system voltage is 480 Y/277 V,an optional 3090 VPM-277-C1 Voltage/Power Module can be used. Thisadd-on module eliminates the need for PTs and provides control power.The optional 3090 CPM-48 Control Power Module is used when 18–60 Vdcis available. A 3090 RTM-317 Ride Through Module is also available whichprovides backup control power for up to 8 seconds depending on thepresence of I/O modules. These modules can be conveniently mounted onthe back of a circuit monitor or on a nearby flat surface. To complete theoffering, Square D manufactures a complete line of control power trans-formers.

Optical Communications InterfaceThe circuit monitor has an optical communications port built into the frontpanel as a standard feature. Using this port, a portable computer with anoptical communications interface (OCI-2000) can retrieve data from thecircuit monitor. The OCI-2000 mounts magnetically to the circuit monitorand provides astandard RS-232interface. Thisinterface can be usedby engineers andmaintenance person-nel to retrievecaptured waveforms,event and data logs,and other informationwithout connecting tothe network.

Circui t Moni tors

The 3090 SMA-220 (left) and the 3090 CMA-100 provideconvenient alternatives to flush panel mounting.

It’s easy to tap into a circuitmonitor using a PC and anoptical communicationsinterface.

An I/O moduleand either a

voltage/powermodule, a control

power module, or aride through module

can mount on theback of the circuit

monitor.

17


SQUARE D12/97

Ci rcui t Moni tors

Technical Specifications

Metering SpecificationsCurrent Inputs (each channel)

Current Range ..................... 0–7.0 A acNominal Current ................... 5 A ac

Voltage Inputs (each channel)Voltage Range ..................... 0–180 VacNominal Voltage (typical) ..... 120 Vac

Freq. Range (50/60 Hz) ........... 45–65 HzFreq. Range (400 Hz) .............. 350–440 HzHarmonic Response—Voltage, Current

Freq. 45 Hz–65 Hz ............... 31st HarmonicFreq. 350 Hz–440 Hz ........... 3rd Harmonic

AccuracyCurrent ................................. +/- 0.20%Voltage ................................. +/- 0.20%Power ................................... +/- 0.40%Energy .................................. +/- 0.40%Demand ............................... +/- 0.40%Power Factor ........................ +/- 0.005Frequency 50/60 Hz ............. +/- 0.01 HzFrequency 400 Hz ................ +/- 0.5 Hz

Control Power Input SpecificationsInput Range, ac .................... 100–264 VacFrequency Range ................ 47–440 HzInput Range, dc .................... 100–350 VdcBurden ................................. 14 VA

Temp. Range (operating) ....... -25 to 70° C† Accuracies apply to CM-2150, CM-2250, CM-2350,

CM-2450 and CM-2452 only. Model CM-2050 meetsa 1% accuracy class for current and voltage, and 2%for energy and demand.

Feature ComparisonFeature CM-2050 CM-2150 CM-2250 CM-2350 CM-2450/2452

Full Instrumentation ✘ ✘ ✘ ✘ ✘

RS-485 Comm Port ✘ ✘ ✘ ✘ ✘Front Panel Optical Comm Port ✘ ✘ ✘ ✘ ✘

1% Accuracy Class ✘

0.2% Accuracy Class ✘ ✘ ✘ ✘

Alarm/Relay Functions ✘ ✘ ✘ ✘

On-board Data Logging ✘ ✘ ✘ ✘

Downloadable Firmware ✘ ✘ ✘ ✘Date/Time for Each Min/Max ✘ ✘ ✘ ✘

Waveform Capture ✘ ✘ ✘

12-Cycle Event Capture ✘ ✘ ✘

Extended Memory 100k 100k/356kSag/Swell Detection ✘ ✘

Programmable for Custom Applications ✘

Ordering Information

Class Type Description

3020 CM-2050 Instrumentation, 1% accuracy3020 CM-2150 Instrumentation, 0.2% accuracy, data logging, alarm/relay functions3020 CM-2250 Waveform capture, plus CM-2150 features3020 CM-2350 Disturbance monitoring, 100k extended memory, plus CM-2250 features3020 CM-2450 Programmable for custom applications, plus CM-2350 features3020 CM-2452 356k extended memory, plus CM-2450 features3020 CM-2000U Circuit Monitor firmware upgrade kit3020 IOM-11 I/O Module: 1 status IN, 1 pulse OUT3020 IOM-18 I/O Module: 8 status IN, 1 pulse OUT3020 IOM-44 I/O Module: 4 status IN, 1 pulse OUT, 3 relay OUT3020 IOM-4411-20 I/O Module: 4 status IN, 1 pulse OUT, 3 relay OUT, 1 analog IN, 1 analog OUT (4-20 mA)3020 IOM-4411-01 I/O Module: 4 status IN, 1 pulse OUT, 3 relay OUT, 1 analog IN, 1 analog OUT (0-1 mA)3020 IOM-4444-20 I/O Module: 4 status IN, 1 pulse OUT, 3 relay OUT, 4 analog IN, 4 analog OUT (4-20 mA)3020 IOM-4444-01 I/O Module: 4 status IN, 1 pulse OUT, 3 relay OUT, 4 analog IN, 4 analog OUT (0-1 mA)3020 RIO-110 2 foot I/O shielded ribbon cable extension3090 OCI-2000 Optical communications interface3090 VPM-277-C1 Voltage/power module for direct connect to 480Y/277V circuits3090 CPM-48 Control power module to connect circuit monitors to 18-60 Vac control power3090 CMA-110 CM2 mounting adapter with accessory compartment3090 SMA-220 Circuit Monitor surface mounting enclosure with hinged cover3090 CMA-100 Circuit Monitor mounting adapter to reduce rear c learance requirements3090 RTM-317 Ride through module for 17 Watt devices (i.e. circuit monitors)

o AMMETER (A)

o VOLTMETER, L-L (V)

o VOLTMETER, L-N (V)

o WATTMETER (W)

o VARMETER (VAr)

o VA METER (VA)

o POWER FACTOR METER

o FREQUENCY METER (Hz)

o DEMAND AMMETER (A)

o DEMAND POWER (W)

o DEMAND POWER (VA)

o WATTHOUR METER

o VARHOUR METER

o THD, CURRENT (%)

o THD, VOLTAGE (%)

o K-FACTOR

CIRCUIT MONITOR

[CT Primary]

[PT Primary]

[Sys. Type]

[Dmd. Int.]

[WH/Pulse]

[Address]

[Baud Rate]

[Nom. Freq.]

[Reset]

[Reset]

[Reset]

[Reset]

[Reset]

[Rst. Min/Max]

[Set Password]

[Accept]

3-PHASE

A (A-B)

B (B-C)

C (C-A)

N

SELECTMETER[Value]

METERS

MIN

MAX

ALARM

[Setup]

KiloMega

PHASE

MODE

OpticalComm Port

9.14222

12.04305

7.35187

.8923

Dimensions Typical Wiring Diagram*

* 3-Phase, 4-Wire WYE with optional metered neutral.(3-Wire Delta and other system types supported.)

Front View

Top View

Side View with Modules

Inches

Millimeters

3.1580

10.35263

5.09129

.8321

4.58116 .56

14

(+)LG

N(-)

IN+ IN- OUT+ OUT- SHLD

20 21 22 23 24

910

1112

56

78

12

34

Va

Vb

Vc

Vn

Ia+

Ia-

Ib+

Ib-

Ic+

Ic-

In+

In-

2526

27

3 PHASEVOLTAGEINPUTS120 VOLTSNOMINAL

AUXILIARYCURRENTINPUTS5 AMPSNOMINAL

3 PHASECURRENTINPUTS5 AMPSNOMINAL

CONTROLPOWER

14 VA

RS-485DATA COMMUNICATIONS

TYPE 1 ENCLOSUREINDOOR USE ONLY

CT ShortingBlock

AØ

BØ

N

Line

Fuses

Fuses

Load

Fuse

Fuse

DisconnectSwitch

CØ

WYE PTCONNECTION(120 V L-NSecondaries)

CTs (5 Amp Secondaries)

CPT(120 or 240 VacSecondary, 14 VA)

True EarthGround

VDS

18


SQUARE D12/97

System Manager™ 3000Software

Flexible ElectricalHistorical Database

• Data sharing fromcentralized openODBC database

• Predefined typicalbilling and powerquality loggingtemplates

• Tabular viewing andtrending of standardand user selectablequantities

• Multiple devicequantity comparisonon same trend plot

• Historical datamanagement archivaland restoring

Real-time PowerManagement

• Multilevel networkalarming

• Task execution (e-mail,paging, resets, fileuploads, etc.) onschedule or uponalarm detection

• Pre-engineered realtime-data displays—tables, bar charts,meter panels

• Event recording andsorting assisttroubleshooting eventsequence

Features

Power information

anytime, anywhere

• Microsoft®

Windows NT® and

Windows® 95

supported.

• Flexible architecture,

from stand-alone PC

to client/server.

• Real-time viewing

with customization

using object

embedding.

• Data sharing with

ODBC database and

DDE over the network.

Integrated DeviceSupport

• More than 1000devices supported perPOWERLOGICnetwork server

• Advanced opensupport for intelligent,compatible monitoringdevices from othermanufacturers—displaying data,alarming, logging, andmanual control

• Complete onlinedevice setup for allSquare D supporteddevices

• Manual and automaticdevice resets eliminateredundant steps

• Manual control andsetup of automaticonboard circuit monitorcontrol aid to avoidsetting peaks

Context-sensitiveonline helpsystem.

Dockabletoolbar allowsquick access tofunctions usedfrequently.

Device listallows easyswitchingbetweendevicesdisplayed.

Meter panelscales withwindow foreasy viewingincludes alarmsetpointmarkings.

Bar chart type list allows easyswitching between bar charttypes displayed. Name of online system

is displayed for quickreference.

Name of system open forediting is displayed. Canbe the online system.

System time.

19


SQUARE D12/97

The System Manager 3000 software (SMS) family and POWERLOGIC®

Power Monitoring and Control Systems provide a total, integrated systemapproach to power management. As a result, accessing power informationand distributing it wherever it’s needed is more easily achieved.

Designed primarily for power system engineers, SMS-3000 software bringsinformation from your power system directly to your desktop. The thirdgeneration of POWERLOGIC power monitoring software, the SMS-3000program runs on Microsoft Windows NT and Windows 95 operatingsystems. The inherent open system and network capabilities of SMS-3000software help users minimize energy costs, reduce peak demand chargesand power factor penalties, and reduce downtime.

Whether your power monitoring application requires a single workstation ora full-featured system of networked computers, the new POWERLOGICSMS-3000 software family offers a variety of functions to make managingand analyzing your power system easier.

Scaleable Solution: Client/Server to Stand-aloneClient/server applications today are not limited to the computing power ofone computer. Instead, they share the workload between multiple comput-ers. With SMS-3000 software, the POWERLOGIC network server handlesall device communications, data logging and storage, and alarm manage-ment tasks. The SMS-3000 client converts the data it receives from theserver into usable formats such as tables, bar charts, and trend plots.

It is not necessary for client PCs to be connected to the POWERLOGICdevice network; only the POWERLOGIC network server is connected tothe device network. SMS-3000 software frees you to position client PCsanywhere on the PC local area network.

Client/Server ProductsSystem Manager 3000 (SMS-3000) software is the client/server productconsisting of one POWERLOGIC network server and one SMS client. TheSMS-1000 software product is an additional client application that can beplaced wherever it is needed. The client is used with SMS-3000 softwarevia a local area network or wide area network.

Stand-alone ProductsSystem Manager 1500 (SMS-1500) and Power Monitoring EXPlorer (PMX-1500) software are stand-alone products with device setup, communica-tion and data displaying capabilities contained on the same PC thus notrequiring the PC local area network. SMS-3000software and SMS-1500 software both supportthe Interactive Graphics Client. See the backcover for feature comparison between productofferings.

FlexibilityOne of the primary features of client/servertechnology is flexibility. The System Manager3000 family allows greater flexibility for powermonitoring systems, whether you need a stand-alone system, multiple POWERLOGIC networkservers, multiple clients, remote clients, remotesites, or even a single database to store datafrom multiple servers. Expand by adding addi-tional clients.

POWERLOGICAPPLICATION

SOFTWARE

Client/Server

ADD-ONMODULE

InteractiveGraphics

Limited

Client/Server network aware software for power monitoring and control. Includes one SMS client and the POWERLOGIC network server.

CompatibleWith:

Self contained stand-alone power monitoring application that does not support networked clients.

Only on same PC with stand-alone products. With SMS-3000, the client application can reside on the same PC or a separate PC from the SMS Client.

FullFeatured

OperatingSystem

Stand-alone

Client Only Additional SMS client to connect to SMS-3000 POWERLOGIC network server.

Description

Single Device Self contained stand-alone power monitoring application that communicates to one device at a time.

Limited FullFeatured

OperatingSystem

Description

PMX-1500

PMX-1000

SMS-3000

SMS-1500

SMS-1000

SMS-121

Windows NT

Windows NTWindows 95


GFX-1000Windows NTWindows 95

SMS-3000SMS-1500PMX-1500SMS-121


System Manager 3000Software

Product Descriptions

20


SQUARE D12/97

SecurityIn addition to the security the Microsoft operatingsystem provides, SMS provides security layersof its own, ensuring that your power system dataare thoroughly protected. SMS supports unlim-ited user accounts, each with a unique nameand password. In addition, SMS supportsprivilege access levels that determine whichfunctions each user can access.

Auto-DialIn some cases, you may want to monitor powersystem information in more than one location.SMS-3000 software offers a auto-dial featuredesigned to dial remote sites on a scheduledbasis and automatically upload the system data.This feature lets users monitor sites acrosscampus or selected remote locations.

Historical Logging and TrendingThe POWERLOGIC system is a collection ofdistributed databases. SMS automaticallycollects the extremely accurate historicalonboard device data logs as well as collectingand storing data for devices without onboardmemory into one centralized ODBC-compliantdatabase. The circuit data can be easily re-trieved, displayed and printed in standardhistorical tabular or trend formats. Custom userselectable styles are also available. For ex-ample, this provides selectable quantities anddifferent interval logging for 24 hours or duringshift hours.

Open DatabaseSystem Manager 3000 software family complieswith the Microsoft Open DataBase Connectivity(ODBC) standards of data storage. This ensuresthat data stored by the POWERLOGIC networkserver can be formatted for any ODBC-compliantdatabase.

SMS-3000 software uses an embedded Mi-crosoft Access® database and is fully tested withboth Microsoft Access and Microsoft SQL®

drivers. Other ODBC-compliant drivers can beinstalled and used if desired.

TasksTasks can be performed when an alarm condi-tion is detected, or on a scheduled basis.Available tasks include launching executableprograms such as paging software packages,soundwave files, device resets, sending elec-tronic mail, uploading onboard device data, andretrieving or capturing a waveform. Scheduledtasks can be executed hourly, daily, weekly,


Stand-alone software allows logging and displayingof information on one PC. Networking is optional.

Remote sites can beautomatically dialedvia model to uploaddata from the devices.

Laptop connection via modemto the POWERLOGIC networkserver for remote alarmacknowledgement.

POWERLOGIC MMSEthernet Gateway

Plant management can monitorentire plant with graphical one linediagram using SMS and GFX-100from a PC within the office.

Etherentconnectionto localareanetwork

Maintenance canmonitor andacknowledgealarms onPOWERLOGICnetwork serverfrom a remote PC.

Accounting can access the databasefor cost allocation without having SMSclient running.

SMS-3000 software creates tend plots of loggedhistorical data. You can display historical informationfor any quantity from any device in the system.

21


SQUARE D12/97

monthly, just once, or at other defined intervals.

ControlSMS-3000 software supports manual control of relay output contacts. Onlyusers with the appropriate user privilege level can access this feature,avoiding accidental or unauthorized usage. Remote-manual control ofoperations, such as initiating a start-up or a load shedding shutdownsequence, can be performed through the software.

Event RecordingSMS uses event recording to track events in your system, from poweroutages to setup changes to manual control. All system-user actions arelogged to the Event Log, which may be viewed, printed, or cleared at anytime. The Event Log is sortable by field, including device, date/time, typeof event, and user name. This aids in future troubleshooting of your systemby showing all information.

Functions/AlarmsSMS supports software alarms for digital and analog inputs in addition todevices that have onboard alarm/event capabilities. Analog and digitalalarm conditions are set up once, then applied to the desired devices andadjusted individually as needed. Conditional logic is also possible whencustom quantities are set as a digital alarm by defining bits in a register.Analog alarm conditions can be set in five condition states (Highest, High,Normal, Low, and Lowest). Each alarm condition can be set to a separateseverity level. When an alarm condition is detected, it is broadcast acrossthe entire SMS-3000 network logged in alarm log, and can initiate auto-matic tasks on the POWERLOGIC network server PC.

Alarm Severity LevelsAnalog and digital alarm conditions can be set for one of 10 severity levels;each can be set for audible and visible required acknowledgment. Eachseverity level can also require a password to acknowledge the alarm. Youcan further customize severity levels by associating a specific color orsound with the level or both.

ResetsSMS supports various resets for all supported device types. For example,circuit monitor minimums and maximums, peak demand currents, andenergy alarms may be reset. You can reset quantities manually or on ascheduled basis, individually, or simultaneously. The date/time of eachreset is stored for each quantity in the Event Log.

Disturbance MonitoringHarmonics—which can lead to increased neutral currents, excessivecapacitor currents, or transformer and motor failure—can be displayedthrough the software. POWERLOGIC circuit monitors use a high-speeddigital sampling technique to monitor the circuit voltages and currents.Circuit waveforms and harmonic content through the 31st harmonic can becaptured and stored for later use.

Waveform AnalysisWaveform information can also be displayed in a “Data Block” format,which includes odd and even harmonic magnitudes, crest factors, andpercent total harmonic distortion (%THD) as defined in IEEE-519. Wave-forms can be further analyzed using waveform analysis software.


Sixty consecutive cycles of waveform display show swell andtwo sags.

Current and voltage waveforms can be viewed simultaneouslyor individually, and can be printed. A data block of harmonicinformation can also be displayed for 4-cycle waveforms.

22


SQUARE D12/97

Easy System SetupMinimal user configuration is required to get a SMS system up and running.Device addresses and a few system and device parameters are all that arenecessary. Devices can be set up individually, or by configuring globalparameters applied to similar devices.

Help SystemComplete, online, context-sensitive help is available anywhere in theprogram. The system is categorized, and any topic may be selected orprinted. Most setup dialog boxes contain a Help button, which is linkeddirectly to information on that dialog box. SMS-3000 software also supportsright mouse button and F1 key functionality.

Real-Time DisplaysSMS supports a variety of real-time data displays, from tables and barcharts to analog meters. SMS-3000 software comes preconfigured withmany standard real-time displays to view any of the thousands of devicequantities

Printing supportAny real-time or historical data that can be displayed in a window ormultiple windows may be saved to a disk or printed, either individually or ina report.

GroupsSelecting devices by function, area, or electrical organization is simplifiedby the configuration of groups. The group feature allows devices andquantities to be organized logically, each with a unique name.

CustomizationSMS is easy to customize, including the ability to create custom tables andadd custom quantities. Custom quantities can be any value read from aPOWERLOGIC device, a metered value from another utility (gas, water,air, etc.), or a dynamic data exchange (DDE) quantity from anotherapplication.

Custom TablesNew tables can be created through a wizard-type user interface. Simplyselect multiple devices and the quantity to be displayed, or select a singledevice with multiple quantities, and the table will be generated. There isalso an advanced custom table utility that allows complete user flexibility ofthe formatting, object embedding, and mathematical manipulation forviewing of a single- or multiple-page table or graph.

Dynamic Data ExchangeDynamic data exchange (DDE) is a standard feature of SMS-3000 soft-ware. With DDE, the user can serve system data to another application,such as an Excel spreadsheet, for advanced reporting or graphing. Inaddition, SMS-3000 software can read, display, log, trend, and even alarmvia DDE from other applications such as building automation systems orprocess control systems.

ReportsSystem Manager software generates reports using any information,including real-time displays. SMS-3000 software supports standard reports


SMS-3000 software offers a variety of predefined andcustomizable real-time data displays.

System Manager software can be easily customized by addingnew devices and quantities, and creating custom tables likethe one shown.

23


SQUARE D12/97

and reports that have been customized. Automatic report generation alsois quick and easy.

Interactive GraphicsThe POWERLOGIC Interactive Graphics Client (GFX-1000) is a colorgraphics client application. It displays system-wide information (one linediagrams, site plans or front elevation drawings) received from thePOWERLOGIC network server on Windows Metafile drawings. GFX-1000can be used with SMS-3000 software or POWERLOGIC stand-alonepackages. When used with SMS-3000 software, GFX-1000 can beinstalled as a separate client on any PC on the local area network. Whenused with stand-alone systems, GFX must be installed on the same PC.


System RequirementsThe table below lists the minimum systemrequirements. The specifications in brackets "[ ]"are recommended for superior performance. Thehard disk requirements for Windows operatingsystem should also be considered whenchoosing a computer.

Operating System

Display Mode

Model

RAM

Hard Disk

Program Size

SY/LINK Card

RS-232 Port

Network Card

Modem

Sound Card

3.5" Drive

CD Drive

SMS-3000PMX-1500SMS-1500SMS-121*

SMS-1000PMX-1000GFX-1000

Windows NT/95SMS-3000 (Windows NT only)

VGA[Super VGA]

VGA[Super VGA]

Pentium 486 / 66[Pentium]

32M 16M [32M]

500M † 500M †

15M 8M

optional

14.4 or 28.8 (opt.)

required

recommended

required required

required required

optional optional

recommended

Numbering xxx-3000 Client/Serverconventions: xxx-1500 Stand-alone

xxx-1000 Clients work with SMS-3000 except GFX-1000works with SMS-3000 and xxx-1500 products

Ordering InformationDescription Class TypeSystem Manager NT Client/Server 3080 SMS-3000

System Manager Client 3080 SMS-1000

Interactive Graphics Client 3080 GFX-1000

Power Monitoring EXPlorer 3080 PMX-1000

System Manager Stand-alone 3080 SMS-1500

Power Monitoring EXPlorer 3080 PMX-1500

System Manager One-to-One 3080 SMS-121

†The amount of memory required on the hard disk depends onwhether the logging data is stored on the same computer.

* System Manager One-To-One (SMS-121 software) uses theserial port to communicate, so the SY/LINK® requirements listedin the table do not apply.

The table below details the features available in the System Manager 3000 softwareproduct family.

Multiple Device Types

Communicate to Multiple Devices

Communicate to Single Devices

Supports Network Clients

Reads DDE Data from other Applications

Supports GFX

Setup Devices and Routing

Real-Time Tables

Bar Charts

Meter Panels

Alarm

Logging

Trending

Waveform Capture

Manual Control

Reports

Automatic Tasks

Customization

Shares SMS Data through DDE on Client

Create Graphical Drawings

Co

mm

un

icat

ion

Use

r In

terf

ace

SMS-3000

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

SMS-1000

PMX-1000

GFX-1000

SMS-1500

PMX-1500

SMS-121

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●

●●

●

●

● ●

● ●

24


SQUARE D12/97

The POWERLOGIC®

Power Monitoring and

Control System offers

direct connection to

Ethernet-TCP/IP

networks to make

power monitoring and

power quality informa-

tion available over new

and existing local and

wide area networks.

From a central

location or many

remote locations, you

can now better

manage your electrical

distribution system

using Ethernet

networking technolo-

gies–as well as the

Internet.

Ethernet Gateway

• Allows communicationswith POWERLOGICcompatible devicesover standard Ethernet-TCP/IP networks

• One or two RS-485serial ports at 19.2KBaud

• Fully TCP/IP and OSIcompliant

• Standard AUI andRJ-45 Ethernet ports

• Up to 10 simultaneouslogical connectionsfrom host device (e.g.,SMS-3000) per RS-485port

• 120/240Vac, 125Vdccontrol power

Features

• On-board security lock-out feature (userconfigurable)

• Integral 12Vdc AUIcontrol power

• Small footprint: 4.76(121)H x 7.25 (184)Wx 9.05 (230)D inches(millimeters)

• Tabletop or wallmounting

• UL, CSA

• 32–140°F (0–60°C)ambient operatingtemperature

• Diagnostic LEDs onRS-485 ports andRJ-45 Ethernet port

Configuration example of a POWERLOGIC Power Monitoring and Control System using Ethernet

Configuration example of a POWERLOGIC Power Monitoring and Control System using Ethernetand an industrial area network

25


SQUARE D12/97

The POWERLOGIC system offers the flexibility to build entire powermonitoring and control systems using Ethernet-TCP/IP (TransmissionControl Protocol/Internet Protocol) as the high-speed network backbone.POWERLOGIC Ethernet connectivity products consist of a gateway deviceand an Ethernet driver for the SMS-3000 family of System Managersoftware products. SMS-3000 power monitoring software operates onMicrosoft Windows 95 and Windows NT. The combination of the gatewayand driver creates a system with optimal communication performance andaccessibility to power system information.

Electrical distribution systems now often have hundreds, and even thou-sands, of communicating devices. A high-speed, high-bandwidth networksuch as Ethernet often becomes necessary to handle the increased datathroughput required. In many cases, an existing Ethernet network can beused to avoid the cost of installing and maintaining a separate “backbone”network.

Ethernet is the most widely supported network in the world. It offers anopen architecture, speed, wide range of connectivity products, and virtuallyunlimited flexibility allowing users to build any size network. These benefitsensure users of their investment in Ethernet as the backbone network ofchoice for power monitoring and control systems.

As your POWERLOGIC system expands (number of users increase, andadditional devices are implemented), so too can your network usingstandard, off-the-shelf products that meet your specific needs.

The POWERLOGIC system allows you to leverage existing Ethernettechnology for power monitoring, power quality, and other information overvirtually any existing communication infrastructure, including the Internet.

Improved System Performance

The POWERLOGIC Ethernet Gateway and the SMS Ethernet Driver havebeen engineered to form a tightly coupled system. Together these compo-nents form the basis for a reliable, high-speed power monitoring solution.The SMS Ethernet Driver allows simultaneous communication requests tomultiple gateways providing faster overall throughput in gathering data fromthe entire POWERLOGIC system.

TCP/IP and OSI Protocols

Many Etherent networks are based on TCP/IP. This is the standard protocolfor delivering information and is what the Internet and many Intranets use.Other network systems utilize the equally powerful Open Systems Intercon-nect (OSI) protocol. The System Manager Ethernet Driver and EthernetGateway support both TCP/IP and OSI protocols. Either protocol is routablethrough existing IP routers, hubs, etc., allowing users to select the protocolstack best suited for their application.

Manufacturing Message Specification (MMS)

The POWERLOGIC Ethernet connectivity solution uses MMS as themessaging protocol over Ethernet. MMS is an international standard (ISO/IEC 9506) for exchanging real-time data and supervisory informationbetween network devices. As an international standard, MMS is notcontrolled by any one entity. Overall, MMS provides a very powerful, highthroughput platform for network communication.

MMS offers increased flexibility in integrating other devices and systemsinto a POWERLOGIC system. The messaging services provided by MMSare broad enough to cover a wide range of applications while the MMSprotocol itself is independent of the application being performed.

Ethernet Gateway

26


SQUARE D12/97

Easy Configuration

Both the System Manager Ethernet driver and gateway are easily config-ured and secured. Standard dialog box setup screens for communicatingwith the gateway reside in System Manager. The gateway has an onboardsetup utility that is easily configured via the RS-232 port using a standardterminal emulator software program, such as Windows Terminal. The setuputility contains all configuration parameters for the gateway as well asdiagnostic parameters. Additionally, an extensive help system is included inthe setup utility. All configuration information is stored in nonvolatilememory and therefore, not affected on loss of control power.

Gateway and Network Integrity

Each serial port contains RS-485 biasing and surge protection circuitry toensure reliable operation where noise may be present from nonlineardevices, electromagnetic induced equipment, or single capacitive couplingof the power system voltages.

Easy Field Upgrades

As features are added to the system components–either in SystemManager, the gateway, or the end devices–the gateway can be easilyupdated via the RS-232 port. This firmware upgrade is accomplishedwithout hardware replacement, lengthy system downtime, or systemreconfiguration.

Support for Existing POWERLOGIC Systems

The POWERLOGIC Ethernet Gateway supports routing into existingSY/NET® network based systems. The RS-485 ports on the gateway canbe connected to another RS-485 port on the network interface module(NIM, PNIM, etc.) making information from the SY/NET network availableover Ethernet. This approach benefits existing facilities wherePOWERLOGIC systems are already in use. Users of existing Square Dnetworks can choose to augment their systems by using Ethernet as thehigh-speed backbone.

System Manager and Client/Server System

System Manager 3000 software uses client/server technology formanaging activity and information on the Ethernet network. This is ideal forsystems where multipleusers need access to powersystem information. ThePOWERLOGIC NetworkServer, which may be adedicated Windows NTworkstation or any one of theuser’s personal computers,‘serves’ requestedinformation to userselsewhere on the networkrunning System Managerclient software. This providesmany users access to theinformation for variousfunctions such as energycost accounting, powerquality monitoring, or maintenance activities. All users share a commonhistorical database through Microsoft’s Open Database Connectivity(ODBC) standard. The ODBC standard is supported by a wide variety ofsoftware vendors as an open solution.

Ethernet Gateway

The POWERLOGIC Ethernet Gateway combinedwith System Manager software brings powersystem information to any personal computer onthe local area network or even the Internet.

27


SQUARE D12/97

Technical SpecificationsControl Power Input SpecificationsInput Range, ac ................. 100-264 VacFrequency .......................... 50/60 HzInput Range, dc ................. 110-300 VdcBurden ............................... Up to 72 VA

Environmental SpecificationsAmbient Operating

Temperature .................... 32° to 140°F(0° to 60°C)

Ambient StorageTemperature .................... -40° to 176°F

(-40° to 85°C)Relative Humidity Rating

(noncondensing) ............. 5 to 95%

Regulatory/Standards ComplianceUL Listed, CSA Certified

Minumum PC Requirements for SystemManager Software (SMS-3000)

• Microsoft Windows NT or Windows 95

• VGA Monitor (Super VGA recommended)

• Pentium processor

• 32MB RAM

• 500MB hard disk (if database on same PC)

• CD ROM recommended

• Standard Ethernet network interface card

• 14.4K Baud modem (28.8K recommended)

• Sound card recommended

Ethernet Gateway

4.76121

9.05230 7.25

184

INCHESMILLIMETERS

Ethernet Gateway Dimensions

Overhead mounting

Optional Ethernet Gateway Mounting Brackets

Left-side mounting Right-side mounting

Ordering Information

Class Type Description

3050 EGW1 POWERLOGIC Ethernet Gatewaywith (1) RS-485 port (up to 8devices)

3050 EGW2 POWERLOGIC Ethernet Gatewaywith (2) RS-485 ports (up to 128devices)

3050 EGWMBK Mounting Brackets Kit

3050 EGWNMC Null Modem Cable

3080 TCPMMS POWERLOGIC Ethernet Driver forSMS-3000 Software family.

28


SQUARE D12/97

The POWERLOGIC

system is a family of

power monitoring and

control products that

provides comprehen-

sive solutions for

power distribution

system management.

The POWERLOGIC

system can help

improve system

reliability, lower

operating costs, and

enhance equipment

utilization. System

Manager software

provides an integrated

solution to remotely

monitor a variety of

intelligent electronic

devices, including the

digital relay.

Digital Relay

• 3-phase and groundovercurrent protection

• User-selectable timecurrent curves

• Local keypad anddisplay of metering andsettings

• POWERLOGIC systemcompatible

• Remote monitoringusing System Managersoftware

• Optional latching ofoutput relay contacts(ANSI 86)

• Self-diagnostics forimproved reliability

• Trip and self-diagnosticindicators

Features

• High level of immunityto electromagneticdisturbances

• Status input for remoteindication of circuitbreaker position

• Removable terminalblocks for ease ofmaintenance

• Supports 1 A or 5 Aphase CT inputs

• Zero sequence currentdetermined by 3-phaseinternal summation

• Optional support ofCSH zero sequencetoroids for externalsensing of ground faultcurrents

• 120 Vac or 48/125 Vdccontrol power options

Typical medium voltage switchgear lineup—one line diagram.

Legend

DR

CMEGWLAN

PowerLogic Digital Relay(50/51 and 50N/51N)PowerLogic Circuit MonitorPowerLogic Ethernet GatewayLocal Area Network

Ethernet High-Speed LAN

Main

FeedersDR DR DR DR

DR CM EGW

29


SQUARE D12/97

Protection and FlexibilityThe POWERLOGIC digital relay accepts current inputs from standard 1-ampere or 5-ampere current transformers, and is suitable for a wide rangeof applications on medium voltage circuits. Time-current characteristics areindependently adjustable for phase and ground from a variety of curveshapes—inverse, very inverse, extremely inverse, and so on. Closetolerances on programmable relay pickup settings and flexible time delayadjustments permit better coordination with upstream and downstreamdevices.

Curve shapes, current transformer (CT) ratios, and relay settings are setusing the simple front-panel keypad and display. The digital relay provides avariety of metering and status information, and supports various capabili-ties from a remote PC.

3-phase Overcurrent (ANSI 50/51)The digital relay senses overloads and short circuits between phases, andinitiates a breaker trip. The relay has both time overcurrent and instanta-neous pickup settings. When a current exceeds one of these settings, thedigital relay displays a “PHASE FAULT” message. After the relay operates,its red trip LED flashes, indicating that a trip has occurred.

Ground Fault (ANSI 50N/51N or 50G/51G)The digital relay senses phase-to-ground faults in resistive grounded,reactive grounded, and solidly grounded networks, and initiates a breakertrip. The relay has both time overcurrent and instantaneous pickup settings.When a current exceeds one of these settings, the relay displays a “GNDFAULT” message. After the relay operates, its red trip LED flashes, indicat-ing that a trip has occurred.

UIT CurveThe digital relay features a new type of inverse-time-overcurrent curveknown as the ultra inverse time curve (UIT). This unique curve providesbetter coordination with fuses and devices that require extreme coordina-tion.

Time Overcurrent SettingsThe digital relay has three settings for time overcurrent: time current curve,current setting, and time delay. Time current curves are divided into twocategories: definite time and inverse-time-overcurrent. For the definite timecurve and the RI curve, the current setting is the tripping pickup.

Instantaneous Pickup Settings

The digital relay has two settings for instantaneous protection: instanta-neous pickup and instantaneous time delay.

AmmeterThe digital relay displays instantaneous phase ammeter readings andphase block demand ammeter readings on the LCD display. By equippingthe digital relay with optional communications, the following values can beviewed on a remote PC:

• Minimum, maximum, and instantaneous currents

• Thermal and block demands (present and peak) with date and time stamp

All values, on both the relay display and over communications, are actualprimary values in A, kA, and seconds.

Digital Relay

5

4

3

1

2

5

4

31

2

On indicator light –Lights when the digital relayis energized.

Self-diagnostic indicator –Lights if an internalfailure occurs.

Trip indicator – Lights when the digital relayoperates a circuit breaker after detecting anovercurrent. A trip message on the displayindicates the type of overcurrent.

16--character LCD display – Displays thefollowing:• Phase ammeter readings• Phase demand ammeter readings• Phase/ground amperes at time of last trip• All setup values• Messages

Keyboard –Use these buttons to advancethrough the digital relay display menus.

30


SQUARE D12/97

Event History InformationThe digital relay provides two types of historical information: trip history andpickup history. The current values at the time of the last trip can be viewedon the LCD display. A more detailed trip history for the last three trips canbe accessed over communications. The trip history includes:

• Cause of trip

• Pickup status at time of trip

• Date and time of trip

• Currents (phase, ground, and 3-phase average)

• Thermal demand (3-phase average and per-phase)

Also, using communications the user can access a date/time history of thelast pickup for time overcurrent and instantaneous overcurrent, for bothphase and ground.

Continuous Self DiagnosticsThe digital relay continually monitors the analog-to-digital conversionchannel, the microprocessor, the memory components, the internal voltagesupply, the integrity of its values, and the internal software program. If thedigital relay detects an internal failure, it inhibits the output relay contactsand operates a watchdog output relay. The watchdog output relay contactscan be connected to an alarm, such as a light or bell, to indicate that aninternal failure has occurred.

For digital relays with communications, the diagnostic status can be viewedon a remote PC. This self-diagnostic feature makes the digital relay morereliable than an electromechanical relay; in electromechanical relays,internal failures can only be detected by periodic manual tests.

POWERLOGIC CompatibleThe digital relay is compatible with POWERLOGIC systems; therefore, it issupported by POWERLOGIC software. The relay can share an RS-485communications link with circuit monitors operating at a baud rate from1200 to 19,200 bps. Digital relays can be daisy-chained with up to 32POWERLOGIC devices over a 10,000 foot (3050 meter) span.

Communications CapabilitiesCommunicating versions of thedigital relay have remote capabilitiessuch as status monitoring, metering,relay reset, and circuit breakeroperations. The digital relay has onestatus input that can be used forremote status monitoring; forexample, indicating circuit breakerposition. In addition, remote phaseand ground current metering, tripevent history, and data logging canbe performed using POWERLOGICsoftware. Remote relay resets andremote circuit breaker operationscan also be performed over thecommunications network.

POWERLOGIC application software configured to display real-time phase and ground currents, circuit breaker status, and triphistory in an easy-to-read, graphic format.

Digital Relay

31


SQUARE D12/97

Time Characteristic Curves

EITUIT VIT

Ultra Inverse Time Extremely Inverse Time Very Inverse Time

10 1001

1000

.100

.02

1.00

10

100

Time

in

seconds

Current in multiples of pickup(I/PHCS or I/GFCS)

12.5

5.0

1.2

2.5

0.8

0.1

0.4

0.2

10 1001

1000

.100

.02

1.00

10

100

Time

in

seconds


5.0

12.5

2.5

1.2

0.8

0.4

0.2

0.1

10 1001

1000

.100

.02

1.00

10

100

Time

in

seconds


5.0

12.5

2.5

1.2

0.8

0.4

0.2

0.1

SIT RI DT

Standard Inverse Time Definite TimeRapid Inverse

10 1001

1000

.100

.02

1.00

10

100

Time

in

seconds


5.0

12.5

2.5

1.2

0.8

0.4

0.2

0.1

10 1001

1000

.100

.02

1.00

10

100

Time

in

seconds


5.0

12.5

2.5

1.2

0.8

0.4

0.2

0.1

10 1001

100

.010

.001

.100

1.00

10

Time

in

seconds


Adjustable

90s

Digital Relay

32


SQUARE D12/97

3-Phase Overcurrent Parameter Settings

Parameter Settings

CT Primary Rated Current (PH CT) A: 10 - 15 - 20 - 25 - 30 - 35 - 36 - 40 - 45 - 50 - 60 - 70 - 75 - 80 - 90 - 100 - 120 - 125 - 150 - 160 -175 - 180 - 192 - 200 - 225 - 240 - 250 - 300 - 320 - 350 - 400 - 450 - 480 - 500 - 600 - 625 - 640 - 700 -750 - 800 - 900 - 960kA: 1 - 1.2 - 1.25 - 1.4 - 1.5 - 1.6 - 2 - 2.5 - 3 - 3.5 - 3.75 - 4 - 5 - 6 - 6.25

Curve (PH TCC) DT - SIT - VIT - EIT - UIT - RI

Current Setting (PH CS in multiples .3 - .35 - .4 - .45 - .5 - .55 - .6 - .65 - .7 - .75 - .8 - .85 - .9 - .95 - 1 - 1.1 - 1.2 - 1.3 - 1.4 - 1.5 -of PH CT) 1.6 - 1.7 - 1.8 - 1.9 - 2 - 2.2 - 2.4 - 2.6 - 2.8 - 3 - 3.5 - 4 - 4.5 - 5 - 5.5 - 6 - 6.5 - 7 - 7.5 - 8 - off

For all inverse-time-overcurrent curves, the PH CS setting range is limited to 2.4 x PH CT.➀

Time Delay (PH TD) ms: 100 - 200 - 300 - 400 - 500 - 600 - 700 - 800 - 900s: 1.1 - 1.2 - 1.3 - 1.4 - 1.5 - 1.6 - 1.7 - 1.8 - 1.9 - 2.0 - 2.1 - 2.2 - 2.3 - 2.4 - 2.5 - 2.6 - 2.7 - 2.8 -2.9 - 3.0 - 3.1 - 3.2 - 3.3 - 3.4 - 3.5 - 3.6 - 3.7 - 3.8 - 3.9 - 4.0 - 4.5 - 5 - 5.5 - 6 - 6.5 - 7 - 7.5 - 8 -8.5 - 9 - 9.5 - 10 - 10.5 - 11 - 11.5 - 12 - 12.5 - 13 - 13.5 - 14 - 14.5 - 15 - 16 - 17 - 18 - 19 - 20 -21 - 22 - 23 - 24 - 25 - 30 - 35 - 40 - 45 - 50 - 55 - 60 - 65 - 70 - 75 - 80 - 85 - 90For all inverse-time-overcurrent curves, the PH TD maximum setting is 12.5 s.

Instantaneous Pickup (PH IP in 1 - 2 - 3 - 4 - 5 - 6 - 7 - 8 - 9 - 10 - 11 - 12 - 13 - 14 - 15 - 16 - 17 - 18 - 19 - 20 - 21 - 22 - 23 -multiples of PH CT) 24 - off

Instantaneous Time Delay (PH ITD) “inst.”: instantaneous, typical tripping time 25 ms.ms: 50 - 100 - 150 - 200 - 250 - 300 - 400 - 500 - 600 - 700 - 800 - 900s: 1 - 1.1 - 1.2 - 1.3 - 1.4 - 1.5 - 1.6 - 1.7 - 1.8 - 1.9 - 2.0

➀ Equivalent to 12 A tap on an induction disc relay.

Ground Fault Overcurrent Parameter Settings

Parameters Settings

CT primary rated current Residual (50 N/51 N) “GF CT=PH CT”: sum of the three phase currents.(GF CT) CSH 120 or CSH 200 “Tor 2A”: 2 A input rating, CSH core balance CTs: equivalent to GF CT=2 A.

“Tor30A”: 30 A input rating, CSH core balance CTs: equivalent to GF CT= 30 A.

Standard zero sequence CT A: 1 - 2 - 3 - 4 - 5 - 6 - 10 - 15 - 20 - 25 - 30 - 35 - 36 - 40 - 45 - 50 - 60 - 70 - 75 - 80 - 90 -with interposing CSH 30 100 - 120 - 125 - 150 - 160 - 175 - 180 - 192 - 200 - 225 - 240 - 250 - 300 - 320 - 350 - 400 -

450 - 480 - 500 - 600 - 625 - 640 - 00 - 750 - 800 - 900 - 960.kA: 1 - 1.2 - 1.25 - 1.4 - 1.5 - 1.6 - 2 - 2.5 - 3 - 3.5 - 3.75 - 4 - 5 - 6 - 6.25

Curve (GF TCC) DT - SIT - VIT - EIT - UIT - RI

Current Setting (GF CS 05 - .1 - .15 - .2 - .25 - .3 - .35 - .4 - .45 - .5 - .55 - .6 - .65 - .7 - .75 - .8 - .9 - .95 - 1 - 1.1 - 1.2 - 1.3 - 1.4 -in multiples of GF CT) 1.5 - 1.6 - 1.7 - 1.8 - 1.9 - 2 - off

Time Delay (GF TD) ms: 100 - 200 - 300 - 400 - 500 - 600 - 700 - 800 - 900s: 1.1 - 1.2 - 1.3 - 1.4 - 1.5 - 1.6 - 1.7 - 1.8 - 1.9 - 2 - 2.1 - 2.2 - 2.3 - 2.4 - 2.5 - 2.6 - 2.7 - 2.8 - 2.9 - 3 - 3.1 - 3.2 -3.3 - 3.4 - 3.5 - 3.6 - 3.7 - 3.8 - 3.9 - 4 - 4.5 - 5 - 5.5 - 6 - 6.5 - 7 - 7.5 - 8 - 8.5 - 9 - 9.5 - 10 - 10.5 - 11 - 11.5 -12 - 12.5 - 13 - 13.5 - 14 - 14.5 - 15 - 16 - 17 - 18 - 19 - 20 - 21 - 22 - 23 - 24 - 25 - 30 - 35 - 40 - 45 - 50 - 55 -60 - 65 - 70 - 75 - 80 - 85 - 90For all inverse-time-overcurrent curves, the GF TD maximum setting is 12.5 s.

Instantaneous Pickup 0.5 - .1 - .15 - .2 -.25 - .3 - .35 - .4 - .45 - .5 - .55 - .6 - .65 - .7 - .75 - .8 - .85 - .9 - .95 - 1 - 1.1 - 1.2 - 1.3 - 1.4 -(GF IP in multiples of 1.5 - 1.6 - 1.7 - 1.8 - 1.9 - 2 - 2.5 - 3 - 4 - 5 - 6 - 7 - 8 - 9 - 10 - offGF CT)

GF ITD “inst.”: instantaneous, typical tripping time 25 ms.ms: 50 - 100 - 150 - 200 - 250 - 300 - 400 - 500 - 600 - 700 - 800 - 900s: 1 - 1.1 - 1.2 - 1.3 - 1.4 - 1.5 - 1.6 - 1.7 - 1.8 - 1.9 - 2

For all inverse time overcurrent curves, the GF CS setting range is limited to 1.0 x GF CT.

Digital Relay

33


SQUARE D12/97

Electrical SpecificationsPhase Current InputsBurden1 A CT configuration ........... <0.001 VA5 A CT configuration ........... <0.025 VACT primary ratings10 .......... A–6250 AStatus InputVoltage range ..................... 20-138 Vac/VdcInput current draw

(max.) .............................. 3 mA @ 20 V;6 mA @ 138 V

Must turn off voltage(max.) .............................. 8.0 Vac/Vdc

Must turn on voltage(min.) ............................... 20 Vac/Vdc

Relay Output Contacts (01)Rated current ..................... 8 A @ 48 Vdc;

8 A @ 127 Vdc/VacBreaking capacity dc resistive load ............... 4 A @ 48 Vdc;

0.7 A @ 127 Vdc/Vac ac resistive load ............... 8 A @ 127 Vdc/VacRelay Output Contacts (02, 03, 04, 05)Rated current ..................... 8 A @ 48 Vdc;

8 A @ 127 Vdc/VacBreaking capacity dc resistive load ............. 2 A @ 48 Vdc;

0.3 A @ 127 Vdc/Vac ac resistive load ............. 4 A @ 127 Vdc/VacControl Power InputsVoltage ............................... 100–127 VacVoltage range ..................... –10, +20%Burden ............................... 16 VAInrush current ..................... <18 A for 10 msOperating frequency .......... 47.5–63 HzVoltage 48–125 VdcVoltage range ..................... ±20%Burden ............................... 12 WInrush current ..................... <12 A for 10 ms

Regulatory/Standards ComplianceSafety ................................. UL 508EnvironmentalOperating temp➀. ................ IEC 68-2 (–5 to +55° C)Storage temp. .................... –25 to +70° CHumidity ............................. 95%, 40° CElectromagneticRadiated emissions ............ FCC Part 15 (Class A)Conducted emissions ......... FCC Part 15 (Class A)RF immunity ....................... IEC 255-22-3 (Class III)Electrostatic discharge ....... IEC 255-22-2 (Class III)Electrical1.2/50 µs impulse

withstand ........................ IEC 255-4 (2 kV for1 min.)

Damped 1 MHzsine wave ....................... IEC 255-22-1 (Class III)

5 ns fast transients ............. IEC 255-22-4 (Class IV)Immunity to surge .............. IEC 801-5Dielectric withstand ............ IEC255-4 (2 kV for

1 min.); UL 508

➀ Ambient cubicle temperature. Relay components maximumoperating temperature is 70° C.

Ordering InformationModel Number Description

DR-LX S01 X0A TEN Digital overcurrent protective relay (3-phase and ground),120 Vac control power*

DR-LX S01 X0A TBN Digital overcurrent protective relay (3-phase and ground),48/125 Vdc control power

DR-LX S01 S0A TEN Digital overcurrent protective relay (3-phase and ground)with data communications, 120 Vac control power*

DR-LX S01 S0A TBN Digital overcurrent protective relay (3-phase and ground)with data communications, 48/125 Vdc control power

CSH 30 CSH 30 core balance CT ground fault sensor



Side View Panel Cutout Top View

8.74222

0.7920

7.80198

7.91201

7.95202

6.38162

6.93176

6.14156

InchesMillimeters

Dimensions

Digital Relay

1

12345678

A

2

AS′

P

1

2

3NL

4

5

120 Vac

1

34

B

Trip RelayContacts

Watchdog OutputRelay Contacts

4

1

5

2

63

Standard Phase CurrentSensing Connections

CCA 650PhaseCurrentSensorModule

Typical Wiring Diagram

*Reliable 120Vac control power is required for proper operation.

34


SQUARE D12/97

MICROLOGIC® Circuit BreakerInterface

Real-time current• A, B, C phase true

RMS currents

• Ground fault current(optional)

Historical data• Date and time of last

trip

• Cause of trip

• Phase currents at trip

• Ground fault current attrip

• Number of overloadtrips

• Number of short circuittrips

• Number of ground faulttrips

Features

Circuit breaker data• Breaker type

• Sensor rating

• Plug rating

• Long time settings:pickup and delay

• Short time settings:pickup and delay

• Instantaneous settings

• Ground fault settings:pickup and delay

PIF-3 interface and other POWERLOGIC devices in a typical POWERLOGIC system

35


SQUARE D12/97

MICROLOGIC Circuit BreakerInterface

The POWELOGIC product interface (PIF-3) for MICROLOGIC circuitbreakers, together with MICROLOGIC full function circuit breakers,provides an economical means to perform remote current monitoring,without the need for additional current transformers or metering equipment.In addition, the product interface reports a wealth of valuable historical tripdata and breaker and breaker data from MICROLOGIC full function circuitbreakers.

The product interface can be mounted in QED switchboards to enable localand remote monitoring of circuit breaker data. The data from up to 32circuit breakers can be displayed using a POWERLOGIC system displayfor circuit breakers, or an IBM PC compatible personal computer equippedwith System Manager software.

Product Interface Mounts Easily in SwitchboardsThe product interface mounts easily in Square D I-Line panelboards andQED switchboards. In new equipment, any MICROLOGIC full functioncircuit breaker can communicate to the product interface.

The Right ConnectionsThe product interface provides eight removable terminal plugs for connec-tion of up to eight MICROLOGIC circuit breakers. Each MICROLOGICcircuit breaker is wired to a communications adapter (CIM3F). Eachcommunications adapter is then connected to the terminal strip on the sideof the product interface.

A removable RS-485 terminal plug is used to daisy-chain the productinterface to other POWERLOGIC compatible devices.


Communications ...................... (1) RS-485, (8)MICROLOGICconnectors

Clock/calendar accuracy .......... +/-4 seconds in 24hours (@25°C)

ElectricalControl power input

Nominal voltage ................... 120 VacOperating range ................... 85-132 VacBurden ................................. 1.1 A @ 120 Vac

(132 VA)Frequency range .................. 47.0 to 65.0 HzIsolation ................................ 2000 V, 1 minute

Ride through on power loss ..... 20 ms @ 120 VacFusing ...................................... 2 A 250 V slow blow+12 V LED................................ Indicates +12 V power

supply OK+5 V LED.................................. Indicates +5 V power

supply OKBattery low LED ....................... When ON, indicates

low battery voltageEnvironmental

Operating temperature ......... 0° to 70°CStorage temperature ............ -40° to +85°CHumidity rating ..................... 95% RH maximum

non-condensing


3050 PIF-3 Product Interface forMICROLOGIC Circuit Breakers*

* One Multipoint Communciations Adapter (3090 MCA-485)and one Multipoint Communications Terminator (3090MCT-485) required per RS-485 communications link.

12VO

KB

ATT

ER

YLO

W5VO

K

Product Interface for

Micrologic

® Circuit B

reakers

66M

AD

EIN

US

A

®

8.875225.4

8.000203.2

.2506.42.999

76.2

0.2506.4

8.375212.7

R

GND

+12V

D-

D+

FUS

E F

U SE FU

SE

FU

SE

250V, 2 A

MP

DC

+-

DC

L40

G39

N38A

CA

CIN+

IN-

OUT+

OUT-

SHLD

RS

485C

OM

MS

MIC

RO

LOG

IC C

IRC

UIT

BR

EA

KE

RS

AD

D +

7A

DD

+ 6

AD

D +

5A

DD

+ 4

AD

D +

3A

DD

+ 2

AD

D +

1

GND

+12V

D-

D+

AD

D +

0

12

34

56

78

910

1112

1314

1516

1718

1920

2122

2324

2526

2728

2930

3132

3334

3536

37

GND

+12V

D-

D+

GND

+12V

D-

D+

GND

+12V

D-

D+

GND

+12V

D-

D+

GND

+12V

D-

D+

GND

+12V

D-

D+

Ground Terminal

Control Power Fuse

Control PowerTerminal Strip

To Micrologic Circuit Breakers(Up to eight per PIF-3)

Communications Adapters (CIM3F)1 required for each Circuit Breaker

RS485 Communicationsto other devices

Product Interface Side View

CommunicationsTerminal Strip

The product interface can communicate to up to eightMICROLOGIC circuit breakers.

7.869199.9

4.375111.1

.378

36


SQUARE D12/97

LIFE-GARD® Model 85ATemperature Controller Interface

Instantaneousreadings• Temperature, Coil A

• Temperature, Coil B

• Temperature, Coil C

• Temperature, hottestcoil

Status• Fan mode (auto/

manual)

• Fan relay (on/off)

• High temperature alarmrelay (normal/setpointexceeded)

• Emergency shutdownrelay (normal/setpointexceeded)

• Transformer type

Features

Setpoints• Fans on

• Fans off

• Alarm on

• Alarm off

• Shutdown

PIF85

M85A

CMPIF3

CB

CB

CB

PIF85

M85A

PIF-85 interface and other POWERLOGIC devices in a typicalPOWERLOGIC system

37


SQUARE D12/97

LIFE-GARD Model 85ATemperature Controller Interface

The POWELOGIC product interface for LIFE-GARD Model 85A tempera-ture controllers brings remote transformer temperature monitoring to thePOWERLOGIC system. Any Square D PowerCast or conventional dry typetransformer, equipped with a LIFE-GARD Model 85A temperature controllercan be monitored for temperature and status. The collected data can bedisplayed and alarmed upon at a remote personal computer using SystemManager software.

The product interface connects to the Model 85A temperature controllerusing standard RS-422 communications. The product interface can belocated up to 4,000 feet from the Model 85A temperature controller.

The product interface provides standard RS-485 communications forconnection to the POWERLOGIC communications link. Multiple productinterfaces and other POWERLOGIC devices can be daisy-chained to aremote personal computer.

The product interface is housed in a steel case designed to be mounted inpower equipment. The compact product interface mounts in low-voltageswitchboards and other small faces. The wiring connections for communica-tions cables and control power are made to removable terminal plugs onthe front of the product interface.


Communications ...................... (1) RS-485(POWERLOGIC), (1)RS-422 (Model 85A)

Clock/calendar accuracy .......... +/-1.5 seconds in 24hours (@25°C)

ElectricalControl power input

Nominal voltage ................... 120 VacOperating range ................... 90-132 VacBurden ................................. 1 A @ 120 Vac

(132 VA)Frequency range .................. 50/60 HzIsolation ................................ 1500 V, 1 minute

Ride through on power loss ..... 20 msSurge suppression ................... 35 JoulesDC OK LED .............................. When lit, indicates DC

power OKRS-422 COMMS LED .............. Flashes when RS-422

comms activeRS-485 COMMS LED .............. Flashes when RS-485

comms activeEnvironmental

Operating temperature ......... 0° to 70°CStorage temperature ............ -40° to +85°CHumidity rating ..................... 95% RH maximum

non-condensingPhysical

Weight (approx.) .................. 3 lbs

0

2

46

8

0

2

46

8

0

2

46

8

0

2

46

8

BAUD

XFMRTYPE

RESET

ADDRESS

RS-422 COMMS

RS-485 COMMS

DC OK

120 VACCONTROLPOWER

GND

L

N

IN+

IN-

OUT+

OUT-

SHIELD

RS-485DATA

COMMS

RS-422TO M85

+-

10

9

8

7

6

5

4

3

2

1

11

12

13

14

15

16

17

18

19

20

®

Address Switches

RS-422 Terminalsfor Connection

To Model 85

RS-485 Terminals forConnection to PowerLogic

Communications Link

Indicating LEDs

Baud Rate Switch

Transformer Type Switch

Control Power Connections

Reset Switch

5.66143.8

4.63117.6

RS-485 Terminals forConnection to PowerLogic

Communications Link

Control PowerDisconnect

120 VAC

L

N

G

Address Switches

Baud Rate Switch

Transformer Type Switch

Reset Switch


3050 PIF-85 Product Interface forLIFE-GARD Model 85ATemperature Controllers

02

46

8

02

46

8

02

46

8

02

46

8

BAUD

XFMRTYPE

RESET

ADDRESS

RS-422 COMMS

RS-485 COMMS

DC OK

120 VACCONTROLPOWER

GND

L

N

IN+

IN-

OUT+

OUT-

SHIELD

RS-485DATA

COMMS

RS-422TO M85

+-

10

9

8

7

6

5

4

3

2

1

11

12

13

14

15

16

17

18

19

20

®

5.66143.8

4.63117.6

4.25108.0 Inches

Millimeters

Product interface front view

38


SQUARE D12/97

Power Management Services

• System design and billof material recommen-dations

• Remote powerswitching systemdesign

• Develop specifications,drawings, documenta-tion

• Automatic controlsystems/PLC ladderprogramming, includingload shed/peak shavingschemes

Features

• Custom hardware/software solutions

• Third party communica-tions interfaces

• Configured worksta-tions, user softwareinterfaces

• On-site installationassistance, componentconfiguration andstartup

• Metering connectionvertification/testing

• On-site and headquar-ters-based customertraining

• Troubleshootingassistance, support forhardware and softwareproducts

• Product upgrades

• Project coordination

Power Management Services provides a complete range of design andoperational services including specifying, developing, installing, commis-sioning, supporting and training users of power monitoring and controlsystems and remote power switching systems. Engineers maintainexpertise in many areas such as communications, personal computers,protective relaying, automatic control systems, and programmable control-lers.

POWERLOGIC WorkstationsSquare D offers a complete systems approach to power monitoring.POWERLOGIC Application and Engineering provides POWERLOGICworkstations–tested and approved personal computers completely config-ured based on the individual system requirements. POWERLOGICworkstations are designed to handle large amounts of system information,

and provide it to those who need it,when they need it. Workstationsplaced in key locations allow plantengineers, operators, maintenancepersonnel, and others to makeinformed decisions using real-timeand historical information.

PM&CS Technical SupportThere are several ways to receive topquality support on POWERLOGICand POWERLINK products;

• Phone: 615-287-3400

• Fax: 615-287-3404

• BBS: 615-287-3414

• Email: [email protected]

• D-Fax: 800-557-4556 (PM&CSIndex is Document #104)

39


SQUARE D12/97

Power Management ServicesPOWERLOGIC University

POWERLOGIC University is a series of training courses designed toimprove your power management skills. The university focuses on how toinstall, use, and maintain your POWERLOGIC systems, and how to get themaximum value from them. The university also gives you an understandingof power, associated terminology, and value of the data the POWERLOGICsystem and products provide. The university provides you with the toolsyou will need to get the most out of your POWERLOGIC system. Coursesare taught at the POWERLOGIC headquarters in LaVergne, TN andregionally.

The university offers courses to certify individuals in installing and maintain-ing POWERLOGIC systems. These courses are geared toward theinstaller, and provide all the necessary knowledge to mount and set up thehardware, install the software, set up and configure communications, anddownload firmware. Certification also provides you with the requiredsoftware tools to fully maintain and test the system.

The university also offers a series of customer training courses designed toimprove your skills with the POWERLOGIC system and associated devices.Customers may attend one or all courses. After each course, a certificate ofcompletion is given, and credits toward a “POWERLOGIC Expert” degreeare recorded. After successfully completing nine credits, you will receive a“POWERLOGIC Expert” diploma and POWERLOGIC shirt.

While attendance at the POWERLOGIC headquarters is ideal, we realizethat time is valuable. Therefore, correspondence courses are also avail-able. Receive the course materials and a test which you complete at yourconvenience and mail back to receive your certificate and credits for thecourse.

An additional option is customer-site training. Any of the POWERLOGICcourses can be conducted at your facility. Courses are also be tailored tomeet your specific training needs.

Engineers, maintenance technicians, electricians, operators, facilitiesmanagers, and others involved in managing a facility’s electrical powerconsumption will benefit from POWERLOGIC university. The curriculum isspecifically designed for the end user and installer.

For contractors and consultants, the curriculum gives you an expertunderstanding of the POWERLOGIC system, allowing you to better serveyour customers. After attending the university, you will be able to specifyand install power equipment correctly. If you obtain product line certifica-tion, you will be added to our published list of certified servicing companies.After becoming a POWERLOGIC system expert, contractors and consult-ants can train their end users.

For course descriptions and schedules contact your local sales office orcall (615) 287-3304 and ask for the POWERLOGIC University TrainingAdministrator.

40


SQUARE D12/97

Power Management ServicesPQ/EM Consulting

Engineering studies• Power system

checkups

• Service reliabilityimprovements

• Harmonic studies

• Power quality andenergy management

• Power system dataanalysis

Features

Monitoring services• On site measurement

• Remote measurement

• Power systemdisturbance reports

• Power managementreports

• Energy use baselines

Technical seminars• Power quality

• Power management

• Power systemmonitoring and datainterpretation

• Energy auditing

• Your site or ours

Engineering solutions for your power management problemsSquare D offers engineering services to solve power management prob-lems in industrial, commercial, utility and institutional facilities. PowerManagement Services includes solving electric power problems, monitoringpower system parameters, training power system users, and cost justifica-tion for managers. Registered professional engineers with utility and facilityexperience identify cost-effective solutions, whether or not the facility isequipped with POWERLOGIC power monitoring and control systems orother Square D systems. Square D provides fully-engineered systemsolutions to your power management problems.

Sample Power Management IssuesHarmonic Distortion - Power systems can absorb a surprising amount ofharmonic currents without adverse effects. However, when harmonicsbecome excessive they can lead to production shutdowns, equipmentfailure, and component overloading. Power factor correction capacitors areparticularlysusceptibleto har-monicdistortionproblems.

Benefits of

Power Management

Services include

• Solving power quality

problems

• Recommending

power system

improvements

• Optimizing

equipment efficiency

• Reducing energy

costs

• Improving service

reliability

• Eliminating

production shutdowns

POWERLOGIC circuitmonitor waveformcapture shows highlevels of current andvoltage harmonicdistortion.

Harmonic distortion decreases the transformercapacity to the point that its true capacity isexceeded for several hours each day.

41


SQUARE D12/97

Power Management ServicesPQ/EM Consulting

Energy Costs - Like power quality, successfulelectricity cost reduction requires more than justpower system data. Here, an industrial plantcollected data from their chiller system, butneglected to analyze its implications. Using thisdata, chiller operating problems and excessivecosts were traced to fouled tubes.

Remote Monitoring - Collecting informationfrom remote locations can be difficult. Square Dcan collect power system data via telephonelines, analyze problems, and produce powerquality and power management reports. Thesereports can be faxed to your desk, or transferredto your computer for cutting and pasting intoyour weekly production report.

Voltage Sags - Sags usually occur due toproblems on the utility system feeding yourfacility. Often it is difficult to distinguish betweensags and interruptions based on equipmenteffects alone. Sag solutions may be far lessexpensive, however, than solutions to interrup-tions, so it is important to capture each event.This data can also be used to pinpoint problemsinside the facility or on the utility system.

Energy Management - Electricity costs aredifficult to reduce when you do not know wherethe energy is being used. Power ManagementServices engineers can help you produce afacility energy profile which identifies energyconsumers, measures their contribution to peakdemand, and recommends no-cost/low-costmethods to reduce costs.

Wiring and Grounding - Many power-relatedproblems occur because basic wiring andgrounding practices are overlooked or allowed todeteriorate. In other instances, recommendedpower schemes are defeated, allowing vacuumcleaners to be plugged into isolated groundcircuits and frequently-started induction motorsto be served from the same transformer assensitive computer supplies.

42


SQUARE D12/97

Year 2000 Compliance

Square D Power Management Operation has evaluated and tested allnecessary POWERLOGIC products for proper handling of the “Year 2000”transition from December 31, 1999 to January 1, 2000. Test criteria alsoincluded a leap year test for February 29, 2000. The following tablesindicate test results for those devices and, where necessary, solutions tohelp ensure a successful Year 2000 transition. This information is subject tochange as additional development and testing occurs.

POWERLOGIC Power Monitoring and Control SystemHardware EvaluationThe internal clock incorporated in hardware devices has been designed toaccount for the Year 2000 transition. The table at the left shows the testresults for POWERLOGIC hardware utilizing an internal clock.

Software EvaluationSystem Manager 3000 software products have been designed to operateas intended for their anticipated useful life, with special design consider-ation given to proper handling of the Year 2000 transition. The SMS-3000products in the table at the right have been tested to verify that the in-tended performance of these software products continues through the Year2000 transition and for a period of time exceeding the anticipated useful lifeof these products.

Portions of EXPlorer, System Manager and communications software(EXP-500, EXP-550, SMS-700, SMS-770, SMS-121 for Windows 3.1 andPSW-101) will work past the Year 2000 date. However, since the softwarewas developed for operating systems such as Windows 3.1 and earlierversions of DOS, some of the time stamping portions will not work. The

known problem areas are history logging,waveform capture and exporting files. Upgradingto the SMS-3000 software family will be neces-sary if these functions are being implemented inyour application. Contact your local Square Dsales representative for upgrade pricing. Refer tothe table at the left for software selection.

POWERLOGIC Product UpgradesSquare D periodically offers upgrades of deviceand system software. In order to maximize thebenefits of the POWERLOGIC Power Monitoringand Control System, and to take full advantage ofdesign improvements, Square D recommendsthat users upgrade and maintain their systems bytaking full advantage of its upgrade offers for thelatest version of firmware and software.

HARDWARE Comments

PM-600, PM-620

Series 2000:CM-2050, CM-2150, CM-2250, CM-2350, CM-2450, CM-2452

Series 200:CM-200, CM-208, CM-244, CM-250

Series 100:CM-100, CM-108,CM-144, CM-150

Power Meters

Circuit Monitors

Digital RelayDR-LX S01 X0A TBNDR-LX S01 X0A TENDR-LX S01 S0A TBNDR-LX S01 S0A TEN

Transformer Temp InterfacePIF-85

MICROLOGIC Breaker InterfacePIF-3

DS Breaker Trip Unit810D

Yes

Yes

Yes

Yes

Yes

Yes

Yes

Yes, when used withSMS-3000 v3.02 orlater only.

SYSTEMSOFTWARE Comments

SMS-3000

SMS-1500

Sys

tem

Man

ager

300

0 v3

.02 Windows NT

Windows Platform(Windows NT 3.51

and above)

Windows 95 or Windows NT

PMX-1500 Windows 95 or Windows NT




SMS-1000

PMX-1000

GFX-1000

SMS-121 Windows 95 or Windows NT

Sys

tem

Man

ager

SMS-700

SMS-770

Windows 3.1

Windows 3.1

EX

Plo

rer EXP-500

Windows 3.1

Windows 3.1

EXP-550

PSW-101 DOS

Co

m

Yes

History logging, waveform captureand exporting files affected. Upgradeto SMS-1500 or SMS-3000.

History logging, waveform captureand exporting files affected. Upgradeto SMS-1500 or SMS-3000.

History logging, waveform captureand exporting files affected. Upgradeto PMX-1500 or SMS-1500.

History logging and exporting files affected. Upgrade to PMX-1500 orSMS-1500.

History logging affected. Upgradeto SMS-1500 or PMX-1500.

SMS-121(v2.23 orearlier)

Windows 3.1History logging, waveform captureand exporting files affected. Upgradeto SMS-121 v3.02 or SMS-1500.

43


SQUARE D12/97

Suggested SystemSpecifications

SECTION 16920-1

POWER MONITORING AND CONTROL SYSTEM

PART 1 GENERAL

1.01 SYSTEM DESCRIPTION

A. Furnish and install a complete Power Monitoring and Control System(PMCS) as detailed on the drawings and as described in this specifica-tion. The system is defined to include, but not be limited to, remotedevices for monitoring, control and protection, device communicationinterface hardware, inter-communication wiring, personal computerworkstations, software, printer where specified, and ancillary equipment.

B. The manufacturer shall demonstrate the system is not a prototype andthat similar systems have been field installed and successfully operatedfor at least five years. The PMCS vendor shall have full responsibilityfor insuring that the PMCS system performs as specified.

C. The PMCS shall utilize Ethernet as the high-speed backbone networkthat supports direct connection of an unlimited number of personalcomputer workstations anywhere on the network.

D. Each Personal Computer Workstation (PCW) connected to the networkshall have equal access to information provided by the power monitoringdevices for centralizing data display, data logging, alarming, eventrecording, and other power monitoring operations. Each PCW shall beindependent of the other PCWs with its own software to allow the user toretrieve and configure the information based on the user’s needs.

E. The high-speed network shall allow direct access to data provided by thepower monitoring devices for implementing automatic control.

F. Application software for personal computer workstations shall beprovided as described in Article 2.11 of this specification.

G. The PMCS shall be POWERLOGIC as manufactured by Square DCompany [or approved equal].

H. All products shall not violate any U. S. patents.

1.02 REFERENCES

A. All Power Meters and Circuit Monitors shall be UL 508 Listed, CSAapproved, and have CE marking.

B. The system shall comply with the applicable portions of NEMAstandards. In addition, the control unit shall comply with FCC EmissionStandards specified in Part 15, Sub-part J for Class A application.

1.03 SUBMITTALS

A. Indicate electrical characteristics and connection requirements. WhenPMCS components are installed by the power equipment manufacturer,the power equipment shop drawings shall clearly identify the compo-nents, the internal connections, and all contractor connections. ThePMCS drawings shall show all PMCS components including necessarycomponent dimensions; type, size, and weight; location of conduit entryand exit; single line diagram indicating external wiring requirements.Drawings shall identify terminal blocks used for interconnections andwire type to be used.

B. Product Data: Provide catalog sheets and technical data sheets toindicate physical data and electrical performance, electrical characteris-tics, and connection requirements.

44


SQUARE D12/97


1.04 QUALITY

A. The PMCS vendor shall be ISO 9000 registered to demonstrate qualitycompliance.

B. PMCS components included within the power equipment lineups shallbe factory installed, wired and tested prior to shipment to the job site.

1.05 SYSTEM START-UP AND TRAINING

A. On-site start-up and training of the PMCS shall be included in the projectbid.

B. Start-up shall include a complete working demonstration of the PMCSwith simulation of possible operating conditions which may be encoun-tered.

C. Training shall include any documentation and hands-on exercisesnecessary to enable electrical operations personnel to assume fulloperating responsibility for the PMCS after completion of the trainingperiod.

D. The project bid shall include [ ] days start-up assistance and [ ]days training to include [ ] trip(s).

E. The power monitoring vendor shall offer regularly scheduled factorytraining for customers on all aspects of power monitoring and control,including:

1. Comprehensive software and hardware setup, configuration, andoperation

2. Advanced monitoring and data reporting

3. Advanced power quality and disturbance monitoring

F. The power monitoring manufacturer shall provide a full time telephonetechnical help center for customers.

PART 2 PRODUCT

2.01 POWER METERS

A. The information provided by the Power Meter shall include the follow-ing quantities:

1. Current, per-phase & neutral2. Volts, phase-to-phase & phase-neutral3. Real Power (kW), per phase & three-phase total4. Reactive Power (kVAR), per phase & three phase total5. Apparent Power (kVA), per phase & three phase total6. Power Factor (true), per-phase & three-phase total7. Frequency8. Demand Current, per-phase & neutral, present & peak9. Real Power Demand (kWd), three phase total, present & peak10. Reactive Power Demand (kVARd), three phase total, present & peak11. Apparent Power Demand (kVAd), three phase total, present & peak12. Real Energy (kWh), three phase total13. Reactive Energy (kVARh), three phase total14. Apparent Energy (kVAh), three phase total15. Energy Accumulation modes, signed, absolute, energy in, energy out16. Total Harmonic Distortion (THD), voltage & current, per phase17. Date and Time Stamping, peak demands, power up/restart and resets

B. The Power Meter shall be accurate to 0.25% of reading plus 0.05% offull scale for voltage and current sensing, and 0.5% of reading plus0.05% of full scale for power and energy, accurate through the 31stharmonic.

45


SQUARE D12/97


1. These accuracies shall be maintained for both light and full loads.

2. No annual recalibration by users shall be required to maintain theseaccuracies.

3. Voltage and current for all phases shall be sampled simultaneouslyto assure high accuracy.

C. The meter shall be UL Listed per UL 508, CSA recognized under C22.2,CE compliant, and tested for EMC in accordance with the IEC 1000-2,1000-4, 1000-5 series of electrical tests (level 4), FCC compliant perFCC Part 15, Class A, and vibration and temperature tested. The metermodule shall be rated for an operating temperature range of 0°C to 60°C.

D. The Power Meter metering inputs shall utilize current transformers forthe current inputs. It shall be rated 5A nominal and 10A full scale. Inaddition, it shall be industrially and utility hardened to have an overloadwithstand rating of 15A continuous and 500A for 1 second.

E. The device shall not require potential transformers or control powertransformers when applied at 600V or less. The power meter shall acceptcontrol power over a range of 90-600Vac, 50 or 60 HZ, or 100-350Vdc.

F. Each Power Meter shall have built-in RS-485 data communications toallow multipoint communication to multiple computer workstations,programmable controllers, and other host devices, up to a data rate of19,200 baud.

G. All information shall be available from the display or via RS-485communications. It shall be possible to perform the setup via thedisplay. No dip switches or other hardware adjustments shall be requiredfor setup.

H. The power meter shall be installed as part of a power monitoring andcontrol system as indicated on the drawings. The RS-485 communica-tions shall provide communications links up to 10,000 feet long.

I. The power meter shall communicate using:

1. The Modbus RTU protocol and connect to any host devices with aModbus-compatible port.

2. The Jbus protocol and connect to any host devices with a J-buscompatible port.

3. The POWERLOGIC protocol and shall connect to any host deviceswith a POWERLOGIC compatible port.

4. The three protocols mentioned above shall reside in the meter fromthe factory and be field selectable as part of setup.

J. The data communications shall be optically isolated to provide reliableoperation.

K. When connected via the network to a POWERLOGIC computer, thepower meter shall provide logging, trending, and alarming information.

L. Each Power Meter shall be equipped with a two-line LCD display asindicated on the project drawings.

M. To facilitate ease in mounting, the display shall be capable of beingmounted up to 50 feet (15 meters) from the metering module using RJ-11 terminated communications cable. Regardless of mountingconfiguration, the display shall always be optically isolated from thepower meter module.

N. The display shall scale readings automatically, without the need formultipliers.

O. All setup information and reset commands shall be password protected.

P. A KYZ pulse initiator for communication of kWh, kVARh, or kVAhinformation to third-party energy management systems shall be pro-

46


SQUARE D12/97


vided.

Q. The power meter shall provide diagnostics to trouble shoot miswiredinstallations.

2.02 CIRCUIT MONITORS

A. Electronic circuit monitors shall provide true rms metered values.Information provided by each circuit monitor shall include frequency,temperature, current, demand current, voltage, real power, reactivepower, apparent power, demand power, predicted demand power, powerfactor, accumulated energy, accumulated reactive energy, total harmonicdistortion (THD) of each current and voltage, and K-factor of eachcurrent.

B. The current and voltage signals shall be digitally sampled at a rate highenough to provide valid data for waveform analysis and true rmsmetering accurate beyond the 30th harmonic (fundamental of 60 Hz).

C. The Circuit Monitors shall be rated for an operating temperature range of-25° C to 70° C and have an overcurrent withstand rating of 500 ampsfor 1 second.

D. All setup parameters required by the Circuit Monitors shall be stored innonvolatile memory and retained in the event of a control powerinterruption. Any battery or other device used to provide non-volatilememory shall be serviceable from the front of the circuit monitor andservicing shall not require removing the circuit monitor from the gear inwhich it is mounted.

E. The Circuit Monitor shall maintain in nonvolatile memory maximum andminimum values for each of the instantaneous values reported as well asthe time and date that the minimum or maximum was set.

F. The Circuit Monitors shall accept inputs from industry standardinstrument transformers (120 VAC secondary PTs and 5 A secondaryCTs). Connection to 480Y/277 VAC circuits shall be possible withoutuse of PTs. In the interest of safety, provision shall be made that if PTsare not used, it shall not be necessary to bring voltages greater than 120VAC (line to neutral) to the Circuit Monitor itself.

1. PT primaries through 1.2 kV shall be supported

2. CT primaries through 32 kA shall be supported

G. The Circuit Monitor shall be accurate to 0.15% of reading plus 0.05% offull scale for voltage and current metering and 0.3% for all power andenergy functions.

1. These accuracies shall be maintained for both light and full loads.

2. No annual recalibration by users shall be required to maintain theseaccuracies.

3. Voltage and current for all phases shall be sampled simultaneouslyto assure high accuracy in conditions of low power factor or largewaveform distortions (harmonics).

H. Any Circuit Monitor may be applied in three-phase, three- or four-wiresystems. A fourth CT input shall be available to measure neutral orground current. If the fourth CT is not used, then a residual current shallbe calculated by vectorial addition of the phase currents. In four-wireconnections the Circuit Monitor shall utilize the circuit neutral commonreference and not earth ground, to provide metering accuracy.

I. The Circuit Monitor shall be capable of being applied without modifica-tion at nominal frequencies of 50, 60, or 400 Hz.

J. The Circuit Monitor shall operate properly over a wide range of controlpower including 100-264 VAC or 100-300 VDC. Connections to 18-60

47


SQUARE D12/97


VDC shall also be available. Ride through capability should also beavailable for backup control power for up to 8 seconds.

K. The Circuit Monitor shall surface or flush mount to an enclosure and beprovided with an attractive finish bezel ring.

1. The Circuit Monitors shall be equipped with an integral, continuousduty, long-life display to provide local access to the followingmetered quantities as well as the minimum and maximum value ofeach instantaneous quantity since last reset of min/max:

2. Current, per phase rms, 3-phase average and neutral (if applicable)

3. Voltage, phase-to-phase, phase-to-neutral, and 3-phase average(phase-to-phase and phase-to-neutral)

4. Real power, per phase and 3-phase total

5. Reactive power, per phase and 3-phase total

6. Apparent power, per phase and 3-phase total

7. Power factor, 3-phase total and per phase

8. Frequency

9. Demand current, per phase and three phase average

10. Demand real power, three phase total

11. Demand apparent power, three phase total

12. Accumulated Energy, (MWh and MVARh)

13. THD, current and voltage, per phase

14. K-factor, current, per phase

15. Reset of the following electrical parameters shall also be allowedfrom the front of the Circuit Monitor:

a. Peak demand current

b. Peak demand power (kW) and peak demand apparent power(kVA)

c. Energy (MWh) and reactive energy (MVARh)

16. Setup for system requirements shall be allowed from the front of theCircuit Monitor. Setup provisions shall include:

a. CT rating [ ]:5)

b. PT rating [ ]:120)

c. System type [three-phase, 3-wire] [three-phase, 4-wire]

d. Demand interval (5-60 min.)

e. Watt-hours per pulse

17. All reset and setup functions shall have a means for protectionagainst unauthorized/accidental changes.

18. For ease in operator viewing, the display shall remain on continu-ously, with no detrimental effect on the useful life of the CircuitMonitor.

L. The Circuit Monitor shall be equipped with a front panel communica-tions port as standard equipment. The port shall be completelyaccessible during normal operation and shall not require exposure of theoperator to life-threatening voltage when in use. The operator shall beable to quickly connect a small Personal Computer (PC) to this portwithout use of tools or splices. This front panel port shall have all of thecommunication functionality of the standard hard wired rear port. Whena connection is made to the front port, the Circuit Monitor shall disregardcommunication from the rear port until the front port is disconnected.

M. It shall be possible to field upgrade the firmware in the Circuit Monitor

48


SQUARE D12/97


to enhance functionality. These firmware upgrades shall be donethrough either the front or rear communication connection. No CircuitMonitor disassembly or changing of integrated circuit chips shall berequired. It shall not be necessary to de-energize the circuit or theequipment to upgrade the firmware.

N. The following metered values as well as the minimum and maximuminstantaneous readings since last reset shall be communicated by theCircuit Monitor:

1. Frequency

2. Temperature

3. Current, per phase rms and neutral (if applicable)

4. Current, 3-phase average rms

5. Current, apparent rms

6. Voltage, phase-to-phase and phase-to-neutral

7. Voltage unbalance, phase-to-phase and phase-to-neutral

8. Power factor, per phase

9. Power factor, 3-phase total

10. Real power, per phase and 3-phase total

11. Reactive power, per phase and 3-phase total

12. Apparent power, per phase and 3-phase total

13. Demand current, per phase and three-phase average

14. Demand real power, three-phase average

15. Demand reactive power, three-phase average

16. Demand apparent power, three-phase average

17. Accumulated energy, (MWh, MVAH, and MVARh)

18. Total Harmonic Distortion (THD), voltage and current, per phase

19. K-factor, per phase

O. All power demand calculations shall be done by any one of the followingcalculation methods, selectable by the user:

⟨ Thermal demand using a sliding window updated every 15 seconds.The window length shall be set by the user from 5-60 minutes infive minute increments.

⟨ Block interval, with optional sub-intervals. The window lengthshall be set by the user from 5-60 minutes in 5 minute intervals.The user shall be able to set the sub-interval length from 5-30minutes in 5 minute intervals.

⟨ External Pulse Synchronization, utilizing a synch pulse providedexternally. An optional status input shall be used to sense the pulse.

⟨ Sliding block interval with continuous sliding 15 second subinter-vals.

1. The following demand readings shall be reported by the CircuitMonitor:

a. Average demand current, per phase

b. Peak demand current, per phase

c. Average demand for real power, reactive power, and apparentpower

d. Predicted demand for real power, reactive power, and apparentpower

e. Peak demand for real power, reactive power, and apparentpower

49


SQUARE D12/97


2. The default demand calculation method shall be a 15 minute slidingwindow thermal demand.

P. Each Circuit Monitor shall be capable of receiving a broadcast messageover the communications network that can be used to synchronizedemand calculations by several Circuit Monitors. This message need notbe addressed specifically to any one Circuit Monitor.

Q. The following energy readings shall be reported by the Circuit Monitor:

⟨ Accumulated energy

⟨ Accumulated reactive energy

⟨ Accumulated apparent energy

1. For real and reactive energy reported values, separate totals forenergy flow in each direction shall be kept, as well as an arithmeticsum.

2. Each Circuit Monitor shall be capable of operating a solid stateKYZ output relay to provide output pulses for a user definableincrement of reported energy. Minimum relay life shall be in excessof one billion operations.

R. All Circuit Monitors shall include current and voltage waveform capturecapability. Waveform capture shall be user selectable for 4, 12, 24, 36,48, or 60 cycles of data.

1. Either type of waveform capture shall be initiated either from aPersonal Computer Workstation (PCW) running the appropriatePower Monitoring and Control Systems software, or by the circuitmonitor as a user defined response to an alarm condition. Inaddition, an external trigger can initiate the 12, 24, 36, 48, or 60cycle waveform. The waveform capture sequence shall be initiatedwithin 1 millisecond after the trigger is sensed. (A user definabledelay shall determine how many of the cycles are shown beforeand after the trigger event.)

2. The Circuit Monitor shall capture, and store in internal memory, 64digitally sampled data points for each cycle of each phase voltageand current.

3. The Circuit Monitor shall transmit the waveform samples over thenetwork to the personal computer workstation for display, archival,and analysis.

4. Each voltage and current of all the phases shall be sampledconcurrently so that proper phase relationships are maintained, sothat harmonic flow analysis can be performed, and so that the effectof a disturbance can be observed on all phase voltages and currents.

5. Harmonic analysis performed on the captured waveforms shallresolve harmonics through the 31st.

6. The data used for the four cycle waveform capture display shall alsobe used to derive metered quantities in order to provide meaningfuladditional data.

7. All waveforms must reflect actual circuit performance. Waveformssynthesized or composed over time shall not be acceptable.

S. Data logging may be accomplished either within the circuit monitor or atthe PCW, or both. Each circuit monitor shall be able to log data, alarmsand events, and multiple waveforms. The monitors shall offer up to 356KB of on-board non-volatile memory. This information shall becommunicated to the PCW upon demand. Logged information to bestored in each Circuit Monitor includes:

1. Up to 14 separate data logs shall be configurable by the user. Eachlog entry shall be date and time stamped. The type of data for the

50


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log shall be selected from a list of 175 monitored values. Each logentry shall be user configurable to consist of from one to over 75values of instantaneous data, depending on the type of data. It shallbe possible to set up each log to take data at a different user definedschedule interval. In addition, it shall be possible for a user todefine an event or new min/max condition that will trigger log fileentries.

2. Data logs can be configured by users to be Fill & Hold or Circular(FIFO).

3. A Min/Max log file shall include the time, date, and value for theminimum and maximum of each of the instantaneous meteredvalues.

4. An alarm and event log shall contain time, date, event information,and coincident information for each user defined alarm or event.This log shall have a capacity of up to 1,000 events selected fromover 100 alarms or events.

5. Waveform logs shall store captured waveforms, 4, 12, 24, 36, 48,and 60 cycle as defined by the user. Waveform log entries shall bescheduled at a user defined interval, externally triggered, or forcedin response to a user defined event. Waveform logs shall be eitherFill & Hold or Circular (FIFO) as defined by the user.

6. A simple user interface shall be available to enable the user toallocate Circuit Monitor memory to different log functions.

T. Circuit Monitor Input/Output Options: Input/Output modules shall befield replaceable. Circuit Monitors shall be equipped with one of thefollowing I/O options as shown on the project drawings:

1. Option One - One solid state output suitable for KYZ pulseinitiation; one solid state input suitable for external end of demandinterval demand pulse detection

2. Option Two - One solid state output suitable for KYZ pulseinitiation; eight solid state status inputs

3. Option Three - One solid state output suitable for KYZ pulseinitiation; four solid state status inputs; three mechanical outputrelays

4. Option Four - One solid state output suitable for KYZ pulseinitiation; four solid state status inputs; three mechanical outputrelays; one analog input, convertible from 0-5 VDC to 4-20 mA;one analog output, 4-20 mA

5. Option Five - One solid state output suitable for KYZ pulseinitiation; four solid state status inputs; three mechanical outputrelays; one analog input, convertible from 0-5 VDC to 4-20 mA;one analog output, 0-1 mA

6. Option Six - One solid state output suitable for KYZ pulseinitiation; four solid state status inputs; three mechanical outputrelays; four analog inputs, convertible from 0-5 VDC to 4-20 mA;four analog outputs, 4-20 mA

7. Option Seven - One solid state output suitable for KYZ pulseinitiation; four solid state status inputs; three mechanical outputrelays; four analog inputs, convertible from 0-5 VDC to 4-20 mA;four analog outputs, 0-1 mA

U. Alarm events shall be user definable.

1. The following classes of events shall be available as alarm events:

a. Over/under current

b. Over/under voltage

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c. Current imbalance

d. Phase loss, current

e. Phase loss, voltage

f. Voltage imbalance

g. Over kVA

h. Over kW or kVAR into/out of load

i. Over/under frequency

j. Under power factor, true or displacement

k. Over THD

l. Over K-factor

m. Over demand, current or power

n. Reverse power

o. Phase reversal

p. Status Input change

q. End of incremental energy interval

r. End of demand interval

s. Over/under analog inputs

t. Current sag/swell

u. Voltage sag/swell

2. For each over/under metered value alarm, the user shall be able todefine a pick-up, drop-out, and delay.

3. There shall be four alarm severity levels in order make it easier forthe user to respond to the most important events first.

4. Indication of an alarm condition shall be given on the front panel.

V. Output Relay Control

1. Relay outputs shall operate either by user command sent over thecommunication link, or set to operate in response to user definedalarm event.

2. Output relays shall close in either a momentary or latched mode asdefined by the user.

3. Each output relay used in a momentary contact mode shall have anindependent timer that can be set by the user.

4. It shall be possible for individual relay outputs to be controlled bymultiple alarms in a wired “OR” configuration.

W. All Circuit Monitors noted on the project drawings shall include sag andswell detection capability. This capability is characterized by thefollowing features:

1. The Circuit Monitor shall continuously monitor for disturbances inthe currents and incoming voltage. There shall be zero blind time;each cycle shall be individually monitored.

2. Disturbance events less than one cycle in length shall be detected.

3. The user shall be able to set a threshold and delay which shall beused by the circuit monitor to determine if an event has occurred.The threshold shall be user defined as either a fixed setpoint orrelative setpoint. When using the relative setpoint, the CircuitMonitor will set the nominal current or voltage equal to its presentaverage value. The Circuit Monitor will automatically adjust thenominal current and voltage values to avoid nuisance alarms causedby gradual daily variations of currents and voltages.

4. Upon detecting a disturbance, the Circuit Monitor shall be capable

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of :

a. Logging a waveform of the event, 12, 24, 36, 48, or 60 cyclesin length, of all phase currents and voltages. The sample rateshall be of sufficient resolution to show the 31st harmonic foreach cycle.

b. Operating any output relay on an optional I/O module.

c. Recording the disturbance into an event log with a date andtime stamp to the millisecond.

d. Causing an operator alarm at the PCW workstation.

5. All data and waveform logs shall be communicated over the localarea network or through the front panel communications port so thatthe user may view and analyze the data using the PMCS softwareand workstation.

X. Where indicated on the drawings, the Circuit Monitors shall be designedto run customized programs to greatly expand the Circuit Monitor’sfunctionality for the particular installation.

1. These programs shall be written in a circuit monitor programminglanguage similar to a compiled “BASIC” language. It shall includethe following capabilities:

a. Scheduled tasks

b. Event Tasks

c. Math functions including: add, subtract, multiple, divide, sine,cosine, square root, etc.

d. Logical functions including: AND, OR, XOR, NOT, shift, etc.

e. Loop commands

f. Compare statements

g. Counters and timers

2. The manufacturer shall offer custom programming services.

3. Changing programs shall not require any physical modifications tothe Circuit Monitor, such as changing computer chips or cards. Allchanges shall be done via either of the communications ports.

4. Examples of custom programs would include:

a. Metering of specialized utility rate structures, including realtime pricing and curtailable rates

b. Data reduction using smart data logging

c. Automatic monthly logging/reset of kWH and Peak Demand

d. Statistical profile analysis of metered quantities

e. CBEMA power quality analysis

f. Calculations for IEEE-519 verification

g. Metering of combined utilities: gas, water, steam, electric

h. Non-critical control schemes, such as load control or powerfactor correction, based on multiple conditions e.g. time of dayand input status

Y. Advanced harmonic information shall be available via the CircuitMonitor. This shall include the calculation of the harmonic magnitudesand angles through the 31st harmonic.

1. This information shall be available for all three phases, current andvoltage, plus the neutral current. (To ensure maximum accuracy foranalysis, the current and voltage information for all phases shall beobtained simultaneously from the same cycle.)

2. The Circuit Monitor shall have a minimum of 100k of on board

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memory to log harmonic magnitudes and angles.

3. The harmonic magnitude shall be reported as a percentage of thefundamental or as a percentage of the rms values, as selected by theuser.

2.03 MOLDED CASE CIRCUIT BREAKER ELECTRONIC TRIPUNITS

A. Electronic Trip Units shall be provided as designated on the projectdrawings. All Electronic Trip Units shall be UL Listed.

B. They shall provide the following breaker/trip unit information to thePMCS network:

1. Breaker frame type (i.e. LE, ME, NE, PE, SE)

2. Breaker sensor rating

3. Rating plug

4. Protective settings

C. The Electronic Trip Units shall provide individual phase and groundammeter information to the PMCS network.

D. The Electronic Trip Units shall provide the following trip information tothe PMCS network:

1. Date/time of last trip

2. Type of last trip (overload, short circuit, ground fault)

3. Magnitude of phase and ground fault at time of last trip

E. The Electronic Trip Units shall provide the following maintenanceinformation to the PMCS network:

1. Number of overload trips

2. Number of short circuit trips

3. Number of ground fault trips

2.04 LOW VOLTAGE POWER CIRCUIT BREAKER TRIP UNITS

A. Low Voltage Power Circuit Breaker Trip Units shall be digital and truerms sensing and provided as designated on the project drawings.

B. The trip units shall be integral to the circuit breaker, and include thefollowing:

1. Unit status indicator

2. Integral testing

3. Adjustable long delay and ampere setting

4. Local mode of trip indicators

5. Rating plug

6. Local hi-load indication

7. [Adjustable short time delay and pickup]

8. [Adjustable ground fault delay and pickup]

9. [Selectable I2t on short time and ground fault]

10. [Zone selective interlocking]

C. The trip unit shall include an integral, four digit, alphanumeric display toindicate the following:

1. Amperes

2. Peak power (MW)

3. Present power (MW)

4. Energy (MWh)

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5. Mode of trip

6. Service trip messages

D. The trip units shall be powered from within the circuit breaker withoutthe need for an external power source. Optionally, control power fordisplay and communication may be provided by an external source asindicated on the project drawings.

E. They shall have the ability to communicate up to 19.2 k baud on thePMCS network without the need for additional communication inter-faces.

F. The trip units shall provide the following breaker identification informa-tion to the PMCS network:

1. Frame size

2. Rating plug and multiplier

G. The following trip information shall be available over the PMCSnetwork:

1. Breaker tripped

2. Cause of trip

3. Time of trip

4. Trip currents: per phase and three-phase average

5. Number of trips by type (i.e. instantaneous, ground, etc.)

H. Breaker status and maintenance information shall be available over thePMCS network including:

1. Breaker open or closed

2. Number of open/close operations

3. Number of breaker trips

4. Breaker loading in percent of capacity based on long delay pickupsetting

I. It shall be possible to operate the breaker remotely via the PMCSnetwork. This function shall be password protected.

J. The following metered values shall be available over the PMCSnetwork:

1. Current, per phase rms, ground, and neutral (if applicable)

2. Current, three-phase average rms

3. Power factor, three-phase

4. Real power, three-phase

5. Accumulated real energy

6. Energy (Wh)

7. Present and peak demand current, per phase, neutral, and three-phase average

8. Present, peak, and predicted demand power (kW).

K. The following values shall also have minimum and maximum readingsavailable:

1. Current, per phase rms, ground, and neutral (if applicable)

2. Current, three-phase average rms

3. Power factor, three-phase

4. Power, three-phase (kW)

L. Energy reported values available over the network, shall include separatetotals for energy flow in each direction, as well as an arithmetic sum.

M. The power demand shall be calculated using the sliding window method

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with a user selected window of 5-60 minutes, in 5 minute intervals.

2.05 TRANSFORMER TEMPERATURE MONITORS

A. Transformer Temperature Monitors shall be provided for each dry-typeand cast resin transformer noted on the project drawings. All Trans-former Temperature Monitors shall be UL Listed.

B. The Transformer Temperature Monitors shall provide the followinginformation to the PMCS network.

1. Coil temperatures - phases A, B, and C

2. Hottest coil temperature

3. Fan relay status

4. Alarm relay status

5. Emergency over-temperature relay status

6. Setpoints for fans, alarm and over-temperature relays

2.06 ELECTRONIC MOTOR PROTECTIVE DEVICES

A. Electronic Motor Protective Devices as noted on the project drawingsshall be able to model (learn) the thermal loading of the motor and cooldown characteristics to maximize protection during continuous and loadcycling operation.

B. Each unit shall be equipped with industry standard RS-485 datacommunications and utilize the same data communication cables as theother power monitoring devices in the system.

C. Historical operating information such as running hours since lastcommissioning, number of starts/trips since last commissioning, numberof overload trips/ground fault trips and similar data shall be displayed onthe front of the device and be available via data communications toprogrammable logic controllers and personal computer workstationsthroughout the PMCS network for control, alarming, data logging, andevent recording.

D. The Motor Protective Devices shall provide fault diagnosis data such aspre-trip motor and ground fault currents, unbalance ratio, and maximumstator RTD temperature.

E. Each motor circuit noted on the drawings shall be equipped with aCircuit Monitor to provide extensive power monitoring information.

F. The Motor Protective Devices shall accept dc control power.

G. Motor Protective Devices shall be UL Listed.

2.07 DIGITAL PROTECTIVE RELAYS

A. Digital protective relays shall be installed as noted on the projectdrawings. These relays shall accept three-phase inputs from industrystandard current transformers with 1 or 5 Amp nominal secondaries.

B. The protective relay shall provide three-phase overcurrent protection(ANSI 50/51) and ground overcurrent protection (ANSI 50/51G or 50/51N).

C. The user shall be able to select a variety of time current curves fromseveral different families. Families of curves shall include definite time,inverse, very inverse, extremely inverse and ultra inverse. All familiesof curves shall be suitable for coordination in typical medium voltageapplications; the ultra inverse curves shall be provided to enhancecoordination with fuses.

D. A front panel keypad and display shall be provided. From this frontpanel it shall be possible to:

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1. Select Time-Current Characteristic curves

2. Set CT ratios

3. Display phase current information

4. Observe Digital Relay trip status

5. Gather diagnostic information about the relay

6. View cause of trip

E. An optional communication port shall be factory available. Over thecommunications provided by this port it shall be possible to:

1. Communicate at up to 19.2 k baud over the PMCS network

2. Operate the breaker by command

3. Communicate instantaneous rms currents per phase and ground anddemand currents per phase to the PMCS software.

4. Communicate breaker status, and type of trip including faultmagnitude to the PMCS software.

5. Communicate the Digital Relay settings to the PMCS software.

F. There shall be two options for control power for the relay:

1. Option 1: 120 VAC

2. Option 2: 48/125 VDC

2.08 SYSTEM DISPLAY UNITS

A. System Display units shall be provided that include easy to read, pre-configured screens displaying data from the electronic trip units in anorganized manner. The system display shall be UL Listed.

B. System Display Installation

1. System Display units shall be installed by the manufacturer in theswitchgear as indicated on the drawings.

2. The System Display units shall be flush mounted on switchgeardoor panels.

C. System Display for Electronic Trip Units

1. System Display units shall be provided for display the dataavailable from selected Electronic Trip Units connected on theindividual data transfer network.

2. The System Display unit shall utilize a 4 line by 20 character, highcontrast LCD technology display with back lighting to provide highreliability and superior readability in all light conditions.

3. The level of back lighting as well as the contrast shall be adjustable.

4. The System Display shall be equipped with a screen saver feature toextend the life of the display.

5. Data shall be displayed in a logically organized manner completewith the proper scaling and units.

D. System Display Keypad

1. The System Display unit shall allow for easy operation by provid-ing a keypad with large keys for operator selections.

2. The keys shall have a raised perimeter and tactile feedback toprovide a positive response even with gloved hand operation.

3. The keys shall be clearly marked to indicate the function andseparated into meaningful groups with display prompting to assistthe user in operation.

4. It shall be possible to sequentially view all available data from aselected device by single keystrokes advancing through the various

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display pages.

5. It shall be possible to view the same pages of data from otherElectronic Trip Units by single keystroke advancing back and forthfrom device to device.

E. System Display Configuration

1. Each System Display unit shall be configured by the manufacturerwith all necessary data.

2. It shall be possible to change the configuration for each SystemDisplay unit using the keypad provided on each display.

3. Access to configuration functions shall be password protected toprevent unauthorized or accidental modification.

F. Resetting Device Data Using the System Display

1. The System Display unit shall permit the reset of the stored min/max values in the electronic trip units.

2. It shall also permit the reset of the accumulated energy values, peakdemands, and the time and date stamps stored in the CircuitMonitors.

3. These resets shall be limited to authorized persons by means ofpassword protection.

2.09 PMCS NETWORK

A. Connecting and Networking of Power Monitoring Devices

1. All data stored in the Power Monitoring Devices shall be accessibleto external devices by means of RS-485 serial communications.

2. It shall be possible to connect from one communications port toanother (daisy-chain) such that up to 32 Power Monitoring Devicesmay be connected to form a continuous communications linkextending up to 10,000 feet.

3. Communications links shall be compatible with the RS-485 multi-drop communications standards.

4. Communication rates on the links shall be adjustable up to 19.2 kbaud to provide acceptable throughput of power monitoring devicedata.

5. It shall be possible to connect up to an unlimited number ofcommunications links into a large network using ethernet hubs toform a high-speed power monitoring and control network.

B. General Network Information

1. The PMCS shall be connected by means of Ethernet as the high-speed backbone network.

2. The high-speed network shall consist of POWERLOGIC EthernetGateways that allow display units, computers, programmablecontrollers, and other higher level or sub-networks to access theelectrical data being gathered by the electronic Circuit Monitors,Electronic Trip Units, Transformer Temperature Monitors, Elec-tronic Motor Protective Devices, and Digital Protective Relays.

3. It shall be possible to add an unlimited number of PersonalComputer Workstations (PCWs) to the high speed network.Addition of a new PCW shall not require any modification to anyexisting PCWs. Adding PCWs shall require only a simple networktap; extensive rewiring or wiring to each group of monitoringdevices shall not be required.

4. Each personal computer connected to the network shall be aWindows NT or Windows 95 workstation with a standard Ethernet

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Network Interface Card (NIC).

C. POWERLOGIC Ethernet Gateways

1. All of the power monitoring devices shall be connected to theEthernet backbone by one or more POWERLOGIC EthernetGateways (EGW) as shown on project drawings.

2. The EGW shall connect to the Ethernet backbone via unshieldedtwisted pair cable (UTP) or fiber optics via an attachment unitinterface (AUI) port.

3. The AUI port shall be equipped with control power (12V) such thatan external power supply is not required to power the transceiver.

4. There shall be indicating LED’s for the Ethernet connections toassist in trouble-shooting. Indicators are required for Transmit,Receive, Collision, Link and Polarity of the connection.

5. The Ethernet Gateway shall support Circuit Monitors, PowerMeters, and other POWERLOGIC-compatible devices through oneor more 4-wire, RS-485 communication ports via standard daisy-chain connections using Belden 8723 or equivalent. Each RS-485serial port shall operate up to 19.2 kbaud. Each RS-485 serial portshall have a corresponding LED to indicate communicationsactivity on the daisy-chain.

6. The EGW shall be fully TCP/IP compliant thereby allowing thepower monitoring software access to power monitoring informationfrom anywhere on the local area network (LAN) or via the WideArea Network (WAN).

7. The protocol used over ethernet by the EGW shall be ManufacturersMessaging Specification (MMS) an international standard (IEC9506) which is an open, well-defined protocol.

8. Setup of the EGW shall be accomplished via an integral, RS-232interface on-board the EGW. All setup parameters shall passwordprotected to guard against intentional and/or inadvertent access. Itshall also be possible via this RS-232 port to upgrade the firmwareof the EGW in the field to accommodate new system features.

9. All Ethernet cabling shall be installed by a qualified data communi-cations cable installer or the electrical contractor qualified to installdata communications equipment. All communications cabling shallbe Category 5 rated for 100MB.

10. The system shall provide for secure operation via an encryptionalgorithm such that unauthorized personnel cannot intentionally orinadvertently alter the communication or setup parameters.

11. A dedicated Ethernet gateway shall be used which requires nohardware adjustments or modifications. Standard personalcomputers (PCs) or programmable logic controllers (PLCs) are notacceptable as gateways to the power monitoring and control devices

12. The Ethernet gateway shall be equipped with an integral powersupply suitable for connection to 120VAC, 240VAC, 50/60Hz, or125VDC input supply. The power supply input shall be fused andreadily serviceable in the field. An external power supply is notacceptable.

13. The EGW shall be small, self-contained, and suitable for mountingin an electrical closet, telephone room or network room. It shallalso be suitable for mounting in instrument compartments inelectrical equipment. It shall be no larger than 5"H x 8"W x 10"Din size. It shall be possible to side or top mount the EGW usingoptional mounting brackets.

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D. Interface to Existing Systems

1. The high-speed network utilized by the PMCS system shall permiteasy interface with the Building Automation System (BAS).

a. Data located in the power monitoring devices and PLCregisters and associated inputs/outputs shall be made availableto the BAS vendor via Circuit Monitor and/or programmablecontroller register lists.

b. Hardware and software required by the BAS to retrieve thisdata from the PMCS data highway shall be the responsibilityof the BAS vendor.

2. The network shall have POWERLOGIC Ethernet Gatewaysinstalled as noted on the project drawings that allow electrical plantinformation flow with existing POWERLOGIC networks.

a. Data located in the power monitoring devices and PLCregisters and associated inputs/outputs shall be made availableto the factory automation vendor via Circuit Monitor and/orprogrammable controller register lists.

b. Hardware and software required by the factory automationsystem to retrieve this data from the PMCS data highway, shallbe the responsibility of the factory automation vendor.

E. Additional Network Media Options

1. Fiber optics shall be installed where shown on the project drawings.Fiber optic modems and interface hardware shall be provided by thePMCS vendor as required. Use of fiber optics shall be transparentto PMCS software and monitoring devices.

2. Telephone modems shall be installed where shown on the projectdrawings. Telephone modems and interface hardware shall beprovided by the PMCS vendor as required. Use of telephonemodems shall be transparent to PMCS software and monitoringdevices.

3. Wireless ethernet shall be installed where shown on the projectdrawings. Wireless ethernet and interface hardware shall beprovided by the PMCS vendor as required. Use of wireless ethernetshall be transparent to PMCS software and monitoring devices.

4. Ethernet shall be used where shown on the project drawings.POWERLOGIC Ethernet Gateways shall be provided by the PMCSvendor and installed as necessary. Ethernet network connectionsshall be established using industry standard Ethernet protocols suchTCP/IP. All components shall work with existing EthernetGateway, Router, and Hub technology. Use of Ethernet shall betransparent to PMCS software and monitoring devices.

2.10 PERSONAL COMPUTER WORKSTATIONS (PCWs)

A. The PMCS shall include Personal Computer Workstations complete withPMCS Application Software as specified as in Article 2.11 of thisspecification, and shall be located as designated on the project drawings.It shall be pre-configured with all software, configuration files, and one-line drawings by the vendor and ready to connect and operate whendelivered to the job site.

B. Hardware Requirements

1. The PMCS system shall also include [ ] factory suppliedPersonal Computer Workstations capable of displaying informationfrom all Circuit monitors.

2. Each Workstation shall consist of a Pentium or higher CPU, color

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VGA monitor, Microsoft Windows NT/Windows 95, networkinterface board or Ethernet communications card, CD-ROM and/or[3.5 in] floppy drive(s), [ ] Mbyte RAM (32 Mbyte minimum),and [ ] Mbyte hard drive storage capability (500 Mbyte free harddisk space minimum).

3. It shall be possible to operate networked computer workstations in aclient/server environment to allow data sharing and viewing with/onany computer on the network. Each workstation shall havecomplete access to all PMCS information. The number of worksta-tions connected on the network shall not be restricted. It shall alsobe possible to have one or more standalone computer workstationsin a monitoring system where PC networking is not required.

C. Software Requirements

1. The manufacturer shall supply PMCS application software whichprovides the operator user friendly access to all Circuit monitordata, breaker/contactor/switch status and manual control, communi-cation alarms, captured waveforms and logged data.

2. In addition to the PMCS application software programs, each PCWshall permit the use of other software programs as desired by theuser.

2.11 PMCS APPLICATION SOFTWARE

A. General

1. The PMCS shall be supplied with user-friendly application softwaresuitable for operation on personal computer workstations whichserve as central control stations by monitoring the devices in thesystem, recording events, indicating alarm conditions, and display-ing and logging device data.

2. The software shall be developed by the manufacturer of themonitoring devices, and shall be designed specifically for powermonitoring.

3. The vendor shall provide a list of all the software needed on theproject and indicate which packages are being supplied.

4. The vendor shall describe the procedure to be used to allow thesoftware to support additional monitoring devices at a future date,including graphics. The description shall be in sufficient detail toallow the user to make the modifications without vendor support.

5. The software shall be configured, not programmed. All softwareshall be configured by the vendor and delivered ready to use. Thisconfiguration shall include preparation of all graphics, displays, andinteractive one line diagrams required as a part of this project.

6. Any development keys or programming tools needed by the user tomake modifications to the screens, interactive one-line diagrams, ordisplays shall be provided by the vendor.

7. The vendor shall pre-configure the software to be ready to displaydata from at least 20 additional monitoring devices that may beadded at a later date. Configuration shall be to the point that whenadditional monitoring devices are added, the user shall only need toconvey to the software the communications address and type of thenew device. The software shall then be able to display all data fromthat device in a format identical to that used for other devices of thesame type.

8. The software vendor shall offer regularly scheduled classes toprovide instruction on using application software and associatedmonitoring devices to manage a PMCS.

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B. Software Options

⟨ Application Software shall be supplied by the PMCS manufacturerto support system configuration, monitoring of the devices, datalogging, alarming, and other operations associated with the PMCS.Each Personal Computer Workstation (PCW) shall be equippedwith PMCS software from the options listed below, as noted on theproject drawings. Different PCWs can have different softwareoptions installed; installation of a given software option on anyPCW shall not limit the software options on any other PCW.

⟨ The software package(s) noted on the project drawings anddescribed below, fully configured by the vendor, shall be provided.

1. Windows NT/Windows 95 Platform

a. Microsoft Windows NT/Windows 95, 32 bit client/serverapplication provides both standalone monitoring and networkconnectivity solutions over the PC LAN or WAN. Networkcapabilities allow remote access and data sharing of real-timepower system information. Applications are designed tomonitor the entire system of power monitoring devices in thebackground for alarms, events, and data logging, allowing theoperator to perform other tasks with the workstation.

b. The following core products shall be provided as noted on theproject drawings. In addition, all add-on modules describedbelow shall be provided as noted in the project drawings.

1) Basic Power Monitoring - Standalone (PMX-1500). Thissoftware package shall operate on either Windows 95 orWindows NT. It shall be used where all of the powermonitoring data shall be retrieved and displayed onindividual PCs.

(a) Shall support over 1000 PMCS devices, and poll allas required.

(b) Shall provide security to protect system data.

(1) Shall support unlimited user accounts, eachwith a unique name and password.

(2) Shall provide ten privilege access levels thatdetermine which functions each user can access.

(3) Set up functions shall be password protected.

(c) Device setup shall be accessible in both on-line andoff-line modes.

(d) Shall permit device setup including configuration ofcircuit monitor data and waveform logs. Shall allowthe user to define circuit monitor alarms andconfigure circuit monitor relay operation.

(e) Shall allow devices and quantities to be organizedinto logical groups (function, location, department,etc.). Groups shall be user defined, each grouphaving a unique name.

(f) Shall provide resets of all supported devices. Shallallow resets by device or by group of devices.

(g) Shall include an on-line, context sensitive helpsystem.

(h) Events shall be recorded in an Event Log.

(1) Event Log shall be capable of holding at least1000 events. The actual number of events shall

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user defined and only be limited by size ofstorage drive.

(2) The Event Log shall record date/time of theevent, event description , and user name (ifapplicable).

(3) The Event Log shall record occurrences that arerelated to the operation of the software such asbreakers opening, or closing, loss of power, lossof device communications, user logon, changesto system setup, etc.

(i) Shall monitor for alarm conditions detected by eachdevice and indicate the alarm at the PCW.

(1) Alarms shall be user defined pick-ups and drop-outs.

(2) Shall include pre-defined system alarms.

(3) Ten severity levels for analog and digital alarmconditions shall be supported.

(4) Each severity level shall provide user selectedindication including audible, visible, and/orrequired acknowledgment.

(5) Alarm severity levels shall allow furthercustomization by requiring password acknowl-edgment of alarms and by associating a uniquecolor and/or sound with the level.

(6) Alarms shall be reported by exception.

(7) At any time, a summary of all active alarmsmay be viewed.

(8) Alarms shall be recorded in the event log.

(9) Alarms shall be on-board or PC-based.

(j) Shall display digital status inputs.

(k) Shall provide real time, user friendly tabular displaysof electric plant information.

(l) Shall log PMCS data to the PC hard disk at userspecified intervals.

(1) Shall be capable of exporting logged data toother file types used by other commoncommercially available software products.

(2) Shall allow logging of non-electrical quantitiessuch as water, gas, steam, and air pressure.

(m) Shall retrieve and display tables of historical datarecorded over time.

(n) Shall provide time trend plots of historical data overtime.

(1) Shall be possible to overlay on the same plotinformation from multiple circuit monitors.

(2) Shall be possible to plot only a portion of thetotal data available.

(3) The user shall be able to specify the beginningand ending date and time of the data to beplotted.

(o) Shall retrieve and display data and alarm and eventlogs created and stored in circuit monitors.

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(p) Shall capture and log waveforms and harmonicinformation based on user specified criteria.

(1) Shall provide graphical waveform displays forthe voltages, phase currents, and residualcurrent monitored by circuit monitors.

(2) The following information shall be calculatedand displayed based on minimum of 4 cycles ofdata:

(a) Total Harmonic Distortion (THD), rmsmagnitudes, peak values, Crest Factors(CF), and magnitudes of the individualharmonics.

(b) All harmonics calculations shall be basedon samples covering multiple cycles inorder to reduce inaccuracies caused bysampling discontinuities.

(3) Shall retrieve, display, and store 4, 12, 24, 36,48, and 60 cycle waveforms from circuitmonitors.

(q) Shall allow Dynamic Data Exchange (DDE).

(1) Shall serve system data to other applicationssupporting DDE for advanced reporting andgraphics.

(2) Shall read, display, log, trend, and alarm DDEdata from other applications.

(3) Shall allow the creation of custom quantities toread DDE quantities from other applicationsand metered values from other utilities (gas,water, steam , and air pressure).

(r) Shall enable monitoring in more than one location bydialing up remote sites and automatically pollingdevices.

(s) Shall comply with the Open Database Connectivity(ODBC) standards of data storage to allow othersoftware products easy access to the stored informa-tion. Shall be possible to format data stored by theserver for any ODBC database.

(t) After power loss and restoration shall restartautomatically, go on-line and resume logging andalarming.

(u) Shall be capable of password-protected control ofsystem operations from the PCW including theoperation of Circuit monitor outputs, PLC outputs,electronic trip units, digital protective relays, andother devices.

(v) Shall allow user to create custom tables for viewingelectric system information in convenient formats.Custom tables shall be easily modified as needarises.

2) Full System Power Monitoring - Standalone (SMS-1500)

(a) Shall have all functionality of Basic Power Monitor-ing - Standalone (PMX-1500) described above andthe additional functionality described below.

(b) Shall include a task manager scheduling capability

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that provides automated program operations forrepetitive tasks. Such tasks shall include scheduledresets, device log and file retrieval, generating andprinting reports, launching executables, sendingemail, and activating beepers. Frequency andexecution of automated tasks shall be user defined.

(c) Shall provide real time, user friendly bar chart andmeter displays of electric plant information.

(d) Shall allow creation of custom real time trend plots,charts, and meter panels for viewing electric systeminformation in convenient formats. Custom displaysshall be easily modified as the need arises.

(e) Shall allow user to develop reports for anydisplayable electrical system information.

(1) Shall provide options to simplify routineprintouts of various data for standard reports.

(2) User shall be allowed to modify reports.

(f) Shall allow the user to save and retrieve computerworkspaces that include user selected graphics,tables, meters, and bar charts.

3) Single Device Monitoring (One device at a time) - Option(SMS-121)

(a) Shall have all functionality of Full System PowerMonitoring – Standalone (SMS-1500) describedabove, with the following exception: the softwareshall communicate with one device at a time.

4) Advanced System Power Monitoring - Client/Server(SMS-3000)

(a) Shall have all functionality of Full System PowerMonitoring - Standalone (SMS-1500) describedabove, and shall provide these functions on the samePC and/or distribute information processing acrossthe PC LAN or WAN. The server shall operate onWindows NT, while the client s may operate onWindows 95 or Windows NT.

(b) Shall display system information on the local PC andon any client PC that is accessible via the PC LANor WAN and has the appropriate PMCS software (seeSection c. below, Optional PMCS software add-onmodules.)

(1) Shall allow connection to network server viamodem to access system information andacknowledge alarms from a PC or laptop at anyremote location.

(2) Shall broadcast alarms across the PC LAN orWAN.

(3) Shall log PMCS data to any logical driveincluding the local computer hard disk and anyremote drive accessible via a network PC orserver.

c. Optional PMCS client software for use with the Windows NTand Windows 95 based, system monitoring applicationsdescribed above include:

1) Power Monitoring Client (PMX-1000) - [requires SMS-

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3000]

(a) Shall be located wherever needed on any PC in themonitoring system connected to the server via LAN,WAN, or modem.

(b) Shall display all system information listed above inBasic Power Monitoring - Standalone (PMX-1500)collected by the network server from the powermonitoring devices.

2) System Manager Client (SMS-1000) - [requires SMS-3000]

(a) Shall be located wherever needed on any PC in themonitoring system connected to the server via LAN,WAN, or modem.

(b) Shall display all system information listed above inAdvanced System Power Monitoring – Client/Servercollected by the network server from the powermonitoring devices.

3) Interactive Graphics Client (GFX-1000) - [requires PMX-1500, SMS-121,SMS-1500, or SMS-3000]. TheInteractive Graphics Client shall reside independently onseparate PCs networked to the server, or on any PC withany other PMCS power monitoring software as indicatedon the drawings.

(a) Interactive Graphics software shall be provided thatis compatible with the PMCS software.

(b) Shall be located wherever needed on any PC in themonitoring system connected to the server via LAN,WAN, or modem.

(c) The software shall display real-time informationcollected by the network server from the powermonitoring devices on custom drawings includingpower one-line system drawings, equipmentelevation drawings, shop floor layouts, legends,process drawings, etc.

(d) It shall be possible to display any of the quantitiesavailable from the power monitoring devices orprogrammable logic controllers in the location, size,and color selected by the user.

(e) The software shall provide the ability to performexecutables and launch other programs.

(f) The Interactive Graphics software shall allow theuser to zoom, scale, and scroll the drawings to thedesired degree of magnification.

(g) The software shall be capable of displaying status ofcircuit breakers (open/closed/tripped), status oftransformer fans (on/off), transformer coil and motortemperatures, power factor capacitors (on/off),POWERLINK AS circuit breaker status and control,and other information available on the PMCSnetwork. The data shall be available in multipleformats value blocks, meters, and bar charts.

(h) From within any drawing the user shall have theability to link and display drawings in a hierarchicalfashion to allow quick access to related drawings.

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(i) The Interactive Graphics software shall allow theuser to manually control various system operationswith proper password entry (e.g. load transfer).

(j) Analog functions blocks shall be included to displaythe condition (e. g. high, low, or alarm) of anymetered quantity such as current, voltage, tempera-ture, etc.

(k) Components shown on one-line diagrams shall becolor-coded based on the on/off status signals formthe device.

(l) Vendor shall supply custom graphic screens based onuser supplied drawings.

2. Software Service Agreement

a. The electrical equipment manufacturer shall include a [ ][1], [2], or [3] years Software Service Agreement whichprovides customer with software upgrades for the softwarespecified above as they are available.

2.12 AUTOMATIC CONTROL

A. Programmable Logic Controllers (PLCs) shall be provided whichcommunicate with the Circuit Monitors Electronic Trip Units, Trans-former Temperature Monitors, Motor Protective Devices, DigitalProtective Relays, and other compatible devices for performing controloperations.

B. Each PLC shall include ladder programs which will direct the automaticcontrol operations as specified.

C. Processor, input, output, and network interface cards shall be provided asnecessary to implement the sensing and automatic control operations.

D. Data pertaining to the automatic control system shall be transmitted viathe PMCS network to the remote personal computer workstations.

1. PLCs and PCWs shall operate independently of each other, andshall not be affected by the operation of any other PCW.

E. At a minimum the application software at the personal computerworkstation shall provide the following:

1. Interactive color-graphics one-line of automatic control system(breaker status, relays status, etc.).

2. All automatic control operations (open/close breaker, relayoperation, etc.) shall be date/time stamped and recorded in an eventlog.

3. Setup and display alarm conditions for automatic control operationsshall be possible with each alarm condition entered in the event log.

4. Manual operator intervention via the keyboard or interactive one-line graphics shall be provided such that any point in the processmay be controlled.

5. Manual intervention shall be password protected to preventinadvertent or unauthorized override of the control scheme.

6. Protective relaying functions, anti-paralleling interlocks, or loadlimits shall not be defeatable.

PART 3 EXECUTION

3.01 INSTALLATION

A. PMCS components, including Circuit Monitors, Electronic Trip Units,

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Transformer Temperature Monitors, Motor Protection Devices, andDigital Relays, included within the power equipment lineups shall befactory installed, wired and tested prior to shipment to the job site.

B. All control power, CT, PT and data communications wire shall be factorywired and harnessed within the equipment enclosure.

C. Where external circuit connections are required, terminal blocks shall beprovided and the manufacturer’s drawings must clearly identify theinterconnection requirements including wire type to be used.

D. All wiring required to externally connect equipment lineups shall beinstalled by the electrical contractor.

E. Contractor interconnection wiring requirements shall be clearlyidentified on the PMCS system drawings.

END OF SECTION

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Glossary of Terms

access – Allowed availability to information on a network.

accumulated energy – A running accumulation over time of the energy monitored ina given circuit. The total energy consumed is obtained by continuouslyintegrating instantaneous real power with respect to time.

accumulated reactive energy – A running accumulation over time of the reactiveenergy monitored in a given circuit.

address – 1) Reference number assigned to a memory location or interfaced device.2) A step in the application program at which a specific instruction can be found(program address). 3) A unique register location used to hold specific data(register address).

ambient temperature – The temperature within an encompassed atmosphere.

analog – A physical quantity, such as voltage or shaft position, that normally variesin a continuous manner.

asum – The arithmetic sum of the magnitudes of the fundamental and individualharmonics as opposed to the vectorial sum.

ANSI – Abbreviation for American National Standards Institure.

apparent power, 3-phase total – The total volt-amps consumed in a 3-phase circuit.

average demand current, Phase A – Average demand for Phase A currentcalculated using a sliding window over a given time interval. Also known asthermal demand current.

average demand current, Phase B – Average demand for Phase B currentcalculated using a sliding window over a given time interval. Also known asthermal demand current.

average demand current, Phase C – Average demand for Phase C currentcalculated using a sliding window over a given time interval. Also known asthermal demand current.

average demand real power – Average demand for real power calculated using asliding window over a given time interval (ranging from 1-60 minutes in 1 minuteincrements for the circuit monitor).

Baud rate – The rate of speed at which information is transmitted overcommunication lines, expressed in bits per second.

bit – A contraction of binary digit, the smallest unit of information in binary notation. Abit is a zero (0) or a one (1), i.e., the binary of number of 0110 consists of fourbits.

bit rate – The rate at which binary digits, or pulses representing them, pass a giovenpoint of a communication line.

channel – A path for electrical transmission of signals between two or more points.

circuit monitor – A multifunction, digital instrumentation, data acquisition andcontrol device capable of replacing a variety of meters, relays, transducers andother components.

circuit monitor label – A user-definable, alphanumeric field associated with thecircuit monitor.

circuit monitor nameplate data – A user-definable, sixteen character field used toidentify a circuit monitor and its use. For example, if the circuit monitor suppliedpower tot he welder on production line 3, the nameplate may be “Welder Line 3”.

coaxial cable – A cable consisting of an outer conductor concentric to an innerconductor, separated from each other by insulating material.

communications link – Equipment, especially transmission cables and interfaces,which complete the communications connections and permit the transmission ofdigital signal data.

communications microprocessor – The circuit monitor microprocessor which isresponsible for communication to/from the host, receiving data from meteringmicroprocessor, accurately maintaining clock and calendar, keeping the min/maxof calculated values, and control of digital inputs/outputs.

continuous rating – Maximum constant load that a device can carry continuouslywithout exceeding its temperature rise specification.

crest factor (CF) – Ratio of peak to rms values of voltage or current. Crest factor isequal to 1.414 for a purely sinusoidal signal.

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Glossary of Terms

CT rating – A user-definable parameter which represents the primary rating of thecurrent transformers connected to the circuit monitor.

current, percent apparent distortion – The difference in percent between the truerms current and the rms value of a pure sinusoid with the same peak current asthe measured waveform.

current Phase-A – The measured rms current of the A Phase.

current Phase-B – The measured rms current of the B Phase.

current Phase-C – The measured rms current of the C Phase.

current, 3-phase average – The simple arithmetic mean of the rms current flowingin the 3 phases.

current transformer – An instrument transformer intended to have its primarywinding connected in series with the conductor carrying the current to bemeasured or controlled.

cycle – Unit of frequency of alternating current, equal to 1/60 second or 16.33milliseconds.

daisy chain – The physical method of cabling devices in series.

demand interval – The time interval used in the average demand calculations forreal power.

device address door – The sliding door located on the rear of the circuit monitorwhich covers the devices address switches.

device address switches – Two ten position rotary switches, accessed from therear of the circuit monitor, which are used to set the address of the circuitmonitor as well as the unit’s Baud rate.

digital – The representation of numerical quantities by means of discrete numbers.

download – To transfer data to a device.

duplex – Two-way data transmission. Full duplex allows simultaneous datatransmission in both directions. Half-duplex allows data transmission in either oftwo directions, but only one direction at a time.

energy management alarms – A user-definable parameter which indicates whenthe alarm set point has been exceeded, records the date and time of the event,and records the maximum level of average demand power eventually reached.

Ethernet – A specification for local communication networks that employs coaxialcable as a passive communications medium to interconnect differnet kinds ofcomputers, information processing products, and offie equipment at a local site.

fiber optics – A medium that uses light conducted through glass or plastic fibers fordata transmission.

flag – A signal device in a microprocessor system that alerts the operator, or thesystem itself, to the occurrence of some desired or undesired event.

frequency – The number of complete cycles of sinusoidal variation per unit of time,expressed in Hz.

full-duplex – Simultaneous two-way transmission through a communicationschannel.

fundamental – Term for value of voltage or current corresponding to the portion ofthe signal at the power frequency. Usually the power frequency is 60 Hz, butmay be 50 Hz (Europe) or 400 Hz (aviation).

gateway – In local area networks (LANs), a computer system and its associatedsoftware that permit two networks using differerent protocols to communciatewith each other. A gateway translates all protocol levels from physical layer upthrough applications layer, and can thus be used to interconnect networks thatdiffer in every detail.

graphics – Methods and techniques for converting data to or from a graphic display.

ground – Conducting path between a circuit or equipment and earth or a conductingbody serving in place of earth.

half-duplex – Two-way, but not simultaneous, transmission of data through acommunications channel.

interface – A device that allows communication between systems or ports ofsystems.

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Glossary of Terms

K-factor – Relates the heating effect of a distorted current in a transformer to asinusoidal current with the same rms magnitude.

kV – Abbreviation for kilovolts (volts x 1,000)

kVA – Abbreviation for kilovolts apparent power

kVAr – Abbreviation for kilovolts reactive power

kW – Abbreviation for kilowatts, real power

kVA – Abbreviation for kilovoltampere, a standard measure of power.

load – 1) A device placed in a circuit to which power is delivered. 2) The process ofentering data into memory.

master-slave – A mode of operation where one data station (the master) controlsthe network access of one or more data stations (the slaves).

metering microprocessor – The circuit monitor microprocessor which does the realtime monitoring of the current and voltage inputs. It reads the A/D converters andmakes the required calculations on the raw data.

millisecond (ms) – One thousandth of a second: 1 x 10-6 or 0.001 second.

multipoint communications – Method of communication in which a single devicecan communicate to multiple devices.

multiprocessing – Executing two or more tasks in memory at the same time.

NEMA Standards – Property characteristics adopted as standard by the NationalElectrical Manufacturers Association.

network – A group of computing devices that are connected to each other bycommunication lines to share information and resources.

non-volatile memory – Memory which retains its contents upon loss of power. Thecircuit monitor stores many values in non-volatile memory.

OHM’s Law – Current (I) in terms of electromotive force (E) and resistance (R) givenby the equation I = E/R.

on-line – Describes equipment or devices which are involved in directcommunications.

operating system (OS) – Integrated programs that work together to manage andimprove the operating effectiveness of a computer or system.

OSI – Abbreviation for Open Systems Interconnection. Network model developed bythe International Standards Organization (ISO).

overvoltage – Occurs when the voltage exceeds a normal or predetermined value.

peak – Value of voltage or current that is the maximum, or minimum, crest value ofthe waveform.

peak demand current Phase-A – The maximum value recorded for averagedemand current for Phase A since last reset.

peak demand current Phase-B – The maximum value recorded for averagedemand current for Phase B since last reset.

peak demand current Phase-C – The maximum value recorded for averagedemand current for Phase C since last reset.

peak demand real power – The maximum value recorded for average demand realpower since last reset.

peripheral – Those devices which support but are not directly involved in theoperation.

point-to-point communications – Method of communication in which a devicecommunicates to only one other device at a time.

polling – A method by which all equipment sharing a communications line can beperiodically interrograted or allowed to transmit without contending for the line;often a reference to a centrally controlled method of accessing a number ofdevices.

potential transformer – An instrument transformer that is intended to have itprimary winding connected in shunt with a power supply circuit, the voltage ofwhich is to be measured or controlled.

power – 1) Rate of energy flow, measured in watts. 2) Torque times speed.

power factor, 3-phase total – The total power factor of a 3 phase circuit calculatedas the 3 phase total real power divided by the 3 phase total apparent power.

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Glossary of Terms

power factor, Phase-A – The cosine of the angular difference between the vetor’sphase A current and phase A-N voltage.

power factor, Phase-B – The cosine of the angular difference between the vetor’sphase A current and phase B-N voltage.

power factor, Phase-C – The cosine of the angular difference between the vetor’sphase A current and phaseC-N voltage.

programmable controller – A solid-state control system which has a userprogrammable memory for storage instructions to implement specific functionssuch as: I/O control logic, timing, counting, arithmetic, and data manipulation.

protocol – A standardized procedure for establishing a communications linkbetween two devices based on such elements as word structure or length.

PT rating – A user-definable parameter which represents the primary rating of thepotential transformers connected to the circuit monitor (assumes 120Vsecondary PTs).

reactive power, 3-phase total – The sum of the reactive power values for each ofthe 3 phases.

read – To copy, usually from one form of storage to another, particularly fromexternal to secondary storage to internal storage.

real power, 3-phase total – The sum of the real power values for each of the 3phases.

real time – Pertaining to the performance of a computation during the actual timethat a related physical process transpires, in order that results of thecomputation can be used in guiding the physical process.

register – A storage area consisting of two bytes or 16 bits of storage.

RMS – Root Mean Square calculation.

RMS-H (Root Mean Square-Harmonic) – The effective value of the the harmonicportion of voltage or current. This quantity provides information about the actuallevel (in volts or amps) of voltage or current harmonics.

router – A device that connects multiple networks together, providing path selectionand alternate routing based on network destination addresses and the status ofthe connected networks.

routing – A technique which allows information to be sent from one device along aspecified path (or route) to another device. The path is mapped by a statementoffering the address of each device along the route.

RS-422 interface – An electrical interface which offers a standard of communicationfor electronic devices. The circuit monitor’s RS-485 interface is RS-422compatible.

RS-485 interface – An electrical interface which offers a standard of communicationfor electronic devices and offers multipoint communications. The circuit monitorutilizes the RS-485 interface.

SCADA – Abbreviation for Supervisory Control And Data Acquisition.

surge – Large, fast pulse of current, potential or power.

system – A collection of units combined to work as a larger integrated unit havingthe capabilities of all the separate units.

system connection – A user-definable variable which indicates whether a specificsystem is a 3-wire or 4-wire system.

terminator – A hardware load employed on the end of a transmission line or cableused to balance the impedance.

THD (Total Harmonic Distortion) – Indicates the degree to which a voltge or currentsignal is distorted.

ThickWire (10BASE5) – Standard Ethernet baseband coaxial cable that serves asthe backbone transmission medium for the local area network. Primarily used forfacility-wide installations.

ThinWire (10BASE2) – A wiring scheme which uses a type of (thin) coaxial cable foruse in Ethernet. Primarily used in office environments.

throughput – Maximum system output, measured in tasks per unit of time.

transient – Pulse, oscillation or momentary deviation.

trim ring – An optional rectangular ring which is mounted to the circuit monitor

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Glossary of Terms

through an electrical panel.

root-mean-square (RMS) – The square root of the mean value of the square of theparameter values during a complete cycle.

unidirectional maibox – A technique used by the circuit monitor’s microprocessorsto exchange information in which each microprocessor has a separate mail boxto transmit data a separate mail box to receive data.

upload – To transfer data from a device.

user-defined parameter – A value which is definable by the user via thecommunications link. The circuit onitor has 13 user-defined parameters.

var – The unit of reactive power in the Internal System of Units.

varhour – The unit of quadrature-energy in the International System of Units.

voltage, Phase A-B – The measured RMS voltage between phases A and B.

voltage, Phase B-C – The measured RMS voltage between phases B and C.

voltage, Phase C-A – The measured RMS voltage between phases C and A.

voltage, Phase A-N – The measured RMS voltage between phases A and Neutral.

voltage, Phase B-N – The measured RMS voltage between phases B and Neutral.

voltage, Phase C-N – The measured RMS voltage between phases C and Neutral.

watt – The unit of power in the Internal System of Units.

watthour – A measure of power equal to 3600 joules.

waveform capture – A circuit monitor feature available in Models CM-2250, CM-2350, and CM-2450/2452 which captures and reports up to 256 data points froma given phase’s current and voltage waveforms.

write – To enter data into a storage device.

Bulletin No. 3000CT9701 December, 1997

Square D, ,POWERLOGIC, POWERLINK,MICROLOGIC, LIFE-GARD, VISI/VAC,POWER-ZONE, SY/NET, and SY/LINK are registeredtrademarks of Square D Company. System Managerand EXPlorer are trademarks of Square D Company.All other product names listed in this document aretrademarks of their respective companies.

© 1997 Square D All Rights Reserved

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