Power Monitoring and Control Systems Catalog. Class 3000

Transcription

1 Power Monitoring and Control Systems Catalog Class 3000

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3 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 and Control Systems Introduction Profitability with power monitoring If you knew where and how to cut peak demand power usage, you could lower your electric bills and your company s cost of product. But how can you, when you have no idea how your demand patterns relate to production? Perhaps you would like to stretch this year s budget by deferring the purchase of a new substation, but you are not sure you have enough capacity to accommodate the vital new process equipment you need to install. Take a chance and the whole line could go down at who knows what cost in downtime. If you only knew where and how much excess capacity you have. Electric utility deregulation is changing the way you buy electricity. But do you know all you need to know about your electrical needs, including the quality of power needed, in addition to knowing when and how much power is needed? Electricity once considered an uncontrollable cost of doing business is brought under control through power monitoring and control systems. With The POWERLOGIC system provides the information you need to control utility costs and, perhaps more important, downtime costs. a power monitoring and control system, a facility engineer has the ability to locate trouble spots and prevent outages or downtime, as well as determine energy use by department or product line. The POWERLOGIC Power Monitoring and Control System from Square D is an innovative total system solution to managing electricity and improving the reliability of power distribution equipment. The POWERLOGIC system combines microprocessor-based instrumentation and control to provide advanced features for industrial, commercial and utility electrical systems. The POWERLOGIC system s exceptionally accurate instruments, highspeed communications network, and fully integrated power monitoring application software make these benefits possible. Controlling costs to maximize profits One of the keys to maximizing profit is by controlling costs. A power monitoring system helps you do that in two ways. It allows you to better know the impact electrical costs have on your operating costs, and gives you the information you need to purchase electricity more cost effectively. From the personal computer on your desk, you can run the world s most powerful monitoring and control system: the POWERLOGIC system. Reduction of downtime Minimizing downtime is critical to the profitability every operation. Unexpected power outages and having key pieces of equipment shut down suddenly is expensive due to the time required to find the source of the problem, correct it, and get production started again. The loss of product adds additional expense. The key is to identify potential problems and correct them proactively. For example, the current on a critical motor may have become higher than normal. A bearing may be failing. The power monitoring system s overload alarm alerts the operator of the situation so the problem can be identified and corrected with a minimum of downtime. 4

5 Improve power quality Power quality concerns include making sure the power delivered to critical machines and processes is both clean and dependable. Computers and microprocessor-based control systems are very sensitive to the quality of power they use. The first step to solving power quality problems is to determine the magnitude of the problem. This is one of the functions of the power monitoring system. Lower energy costs The power monitoring system can help lower energy costs in several ways. First, demand charges can often be reduced through the analysis of maximum and minimum readings and reviewing time and trend plots of data logs. Alarms can be triggered to warn when the system is in danger of creating new peaks. Second, power factor penalties can be reduced by using power factor correction capacitors (PFCs). But to use PFCs correctly, you need to know what your power factor is and the harmonic content of the circuit. The power monitoring system can be used to determine when and where capacitors should be used. Finally, the POWERLOGIC system provides you with the information about your power requirements so you can take full advantage of the electrical utitlity deregulation opportunities. Allocate energy costs More and more companies want to know not only how much energy they are using, but where they are using it. Competitive pressures necessitate knowing all the costs associated with a product, including the cost of power to produce it. In addition, efforts to closely manage energy costs are easier to evaluate when the costs are broken down by area. The POWERLOGIC system can create the trend plots and reports allocating the energy costs the way you need them. Better utilization of power distribution equipment A common question asked is Does the existing distribution equipment have enough capacity? A power monitoring system with the POWERLOGIC software displays the data logs in the form of time trend plots. Peak information from date and time stamps of maximum readings is also useful. This shows which distribution equipment is under utilized, or near overload. All this information can be used to obtain the maximum use of existing equipment, and to more accurately design future distribution equipment. POWER MONITORING & CONTROL SYSTEMS Power Monitoring and Control Systems Introduction Special monitoring and control systems Power monitoring is often just part of the solution. Monitoring other utilities such as gas, water, and steam may be needed. Sequence of events monitoring can be critical. Monitoring and control of generators and transfer switches may be required. Automatic control systems for Typical POWERLOGIC power monitoring and control system. 5

6 Power Monitoring and Control Systems Introduction shedding and restoring loads may be key to minimizing energy costs or maintaining critical circuits. There are POWERLOGIC solutions for all these systems. How do power monitoring and control systems work? Power monitoring systems monitor the flow of electrical power in circuits throughout the plant. In the POWERLOGIC system, highly accurate circuit monitors and power meters are dedicated to power monitoring, while other compatible devices collect additional equipment information from protective relays, circuit breakers, transformer temperature controllers, and panelboards. Electrical data such as current, power, energy, waveforms, and equipment status is passed over a data network to one or more personal computers. The personal computers run power monitoring application software that retrieves, stores, organizes, and displays real-time circuit information in simple, usable formats. The information collected and stored in a power monitoring system helps operate a facility more efficiently. Of course, the quality of the data depends on the accuracy of the instrumentation and the usability of the display formats. A POWERLOGIC system provides this accuracy in a format that is easy to use and understand. Accurate monitoring devices Each POWERLOGIC monitoring device is a multi-function, digital instrumentation, data acquisition device capable of replacing a variety of meters, relays, transducers, and other components. POWERLOGIC system devices can be integrated with Square D s electrical power distribution products or retrofit into existing equipment. The result is a distributed network of intelligent, accurate monitoring devices reporting to one or more centralized locations. Flexible connectivity and network topologies All POWERLOGIC-compatible devices are equipped with an RS-485 network communication port for integration into a POWERLOGIC power monitoring and control system. Up to 32 devices can be daisy-chained and directly connected to a personal computer, system display, Ethernet gateway (TCP/IP and OSI), or POWERLOGIC network interface module (PNIM). Square D can provide industrially hardened local area networks, or connect to existing networks, either local or wide area. Other communication options such as fiber optics and modems, including telephone and radio, are also available. The POWERLOGIC system makes it easy to allow localized, distributed, remote, and any mixed network combination. 6 No other monitor gives you more standard communications capabilities than the POWERLOGIC circuit monitor. And once the data gets to your computer, there s no better way to make sure of all the information than System Manager 3000 software. Powerful software solutions The POWERLOGIC application software series offers a variety of power monitoring solutions, allowing you to monitor, display, and store vast amounts of information from all of the POWERLOGIC compatible devices. Organized and usable information The POWERLOGIC application software series automatically integrates real-time circuit information into organized and usable formats. Without any custom

7 Power Monitoring and Control Systems Introduction programming and very minimal setup, the user can readily access real-time and historical data, time trend plots, alarms, waveform plots, power quality information, data logging, output control, and more. Evaluation, engineering, and support Square D s Power Management Organization is more than power monitoring devices and software. It includes highly trained and capable engineers evaluating and providing solutions to power quality issues. To ensure smooth installation and system commissioning, our application engineering services are available to oversee the project from design to completion. The POWERLOGIC University provides users with the training needed to get the most out of their system. And finally, the Technical Support Group provides the answers to the questions to ensure smooth operation of your power monitoring system. Information is power If you can t measure it, you can t control it. And controlling costs is critical. POWERLOGIC power monitoring systems provide you with the information you need to make the sound business decisions needed in today s marketplace. 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. 7

8 Power Meters 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 Economical Metering Solution A single, economical device that replaces a full complement of analog meters Accurate true RMS metering of distorted currents and voltages up to the 31st harmonic THD readings for each metered phase of current and voltage to assist in measurement of power quality data Neutral current monitoring to detect overload neutrals Individual machine load monitoring Available feeder capacity monitoring (peak demand current) Load monitoring for predictive maintenance/troubleshooting Remote meter reading and data logging from a personal computer using POWERLOGIC System Manager software and RS-485 communications Ease of Installation Display mounts in panel cutout of standard 1% analog meters Separate meter and display modules allows flexible mounting options Easy retrofit into existing power equipment Direct Connect Up to 600 V No PTs required up to 600 V No separate control power required on up to 600 V circuits Communications Options POWERLOGIC communications for integration with a POWERLOGIC power monitoring system Modbus RTU communication for integration with other systems KYZ pulse initiator for communication to energy management systems 2-Line LCD Display Mounts back-to-back or up to 50 feet from power meter module Use as a portable power meter programmer Provides setup and display of metering information Provides optical isolation from 600 V metering connection Designed for Reliability Tested for compliance with UL and CSA requirements FCC compliant (Class A) CE marking Vibration and temperature tested valuable power information. 8

9 Power Meters Basic Metering Solution and More The POWERLOGIC Power Meter is designed for use in basic power metering applications. It can replace conventional metering devices such as ammeters, voltmeters, and watt-hour meters while providing powerful capabilities not offered by analog metering. The power meter s true rms readings (31st harmonic response) accurately reflect non-linear circuit loading more than conventional analog metering devices. The power meter calculates the neutral current, which can assist in identifying overloaded neutrals due to either unbalanced single phase loads or triplen harmonics. Circuits can be closely monitored for available capacity by keeping track of the peak average demand current. Accurate circuit loading information is essential to get the most out of existing power equipment while maintaining power system reliability. The power meter provides a full complement of accurate true rms metering values through the optional display, or via the standard RS-485 communication port to a POWERLOGIC Power Monitoring and Control System. A model PM-600 power meter module replaces a full complement of basic analog meters including a watt-hour meter. The model PM-620 power meter module extends the metering capabilities to report power and current readings including the date and time of occurrence. The model PM-620 also provides neutral current and per phase THD for each metered current and voltage. Refer to the tables for information about the metering values reported by each model. A KYZ output is included to communicate energy and demand information to third party energy management systems. Meter Feature Values Model Model PM-600 PM-620 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 and Modbus RTU communications Date/time stamping Peak demands, power up/restart, resets THD, voltage & current A, B, C POWERLOGIC Power Meter Feature Comparison Mounting Flexibility The power meter s small size and variety of mounting configurations allow it to be readily installed in new equipment or retrofit into existing equipment. The power meter module can be mounted onto a 35mm DIN rail, or it can be mounted on any flat surface using its four mounting feet. For added simplicity in retrofit installations, the panel mounting hole patterns for both the power meter module and the optional power meter display match the conventional 4-inch ammeter/voltmeter spacing so the meter and the display can be mounted back-to-back on opposite sides of a panel surface. In metering installations of 600 V and below, the power meter provides additional savings in both cost and mounting space by eliminating the need for PTs and control power transformers. Versatile Display The optional power meter display mounts in the same space as a conventional 4-inch ammeter and is connected to the power meter module with a communication cable. With the 2-line by 16-character LCD display, the user can view metering data, and access the password protected meter setup and resets menus. Since the power meter display can be mounted up to 50 feet Power Meter Display Power Meter Module away from the power meter module, power metering can now be installed in tight equipment spaces without sacrificing convenient and affordable local display. The communications port on the power meter display is optically isolated from the 600 V metering connections. 9

10 Power Meters Power Meter Display (PMD-32) 4 Power Meter Module (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 Powerful Functionality The power meter accepts inputs from standard 5 A CTs and has full scale input of 10 A. The voltage inputs can be directly connected to 3 phase circuits of 600 V and below without the need for PTs or CTs. For higher voltage circuits, the power meter accepts a full range of PT primary values with control power derived from the PTs or from a separate source of ac or dc control power. Setup and resets are password protected and are easily done through the power meter display or via the network using System Manager software, releases SMS-3000, SMS-1500, and PMX From the optional display, POWERLOGIC or Modbus RTU protocols can be selected. No DIP switches or other hardware adjustments are required for setup. All readings are scaled to their actual values without the need for a multipler. POWERLOGIC System Compatibility The power meter supports standard POWERLOGIC RS-485 communications up to 19,200 Baud with communications links up to 10,000 feet. A meter can quickly be installed into any existing POWERLOGIC system. The power meter has been fully integrated into the latest POWERLOGIC application software, System Manager software, releases SMS-3000, SMS-1500, and PMX This software enables users to manage their electrical distribution systems by providing tabular and graphical data displays, alarms, real time and historical time trend tables and graphs, and reports. Power meter setup and reset operations and wiring diagnostics can also be performed from a remote personal computer using the software. POWERLOGIC power monitoring devices and systems assist in equipment monitoring for cost allocation, troubleshooting, predictive maintenance, planning, and more. The lower installed cost of the power meter makes it possible for facilities to monitor many smaller, less critical feeder circuits enabling whole facility power monitoring. 10

11 Power Meters Typical Wiring Diagram* * 3-Phase, 4-Wire WYE. (3-Wire Delta and other system types supported.) Technical Specifications Metering Specifications Current Inputs Current Range A ac Nominal Current... 5 A ac Overcurrent Withstand A, 1 second Burden VA Voltage Inputs Voltage Range V ac Nominal Voltage /120, 480/ 277, 600/347 V rms Input Impedance... >2 Megohms Frequency Range (50/60 Hz) Hz Accuracy Current % Voltage % Power % Energy % Demand % Power Factor % Frequency 50/60 Hz Hz Control Power Input Specifications Input Range, ac V ac Frequency Range Hz Input Range, dc V dc Burden... 5 VA Nominal Temperature Specifications Meter Module (operating).. 0 to 60 C Meter Display (operating).. 0 to 55 C Dimensions INCHES MILLIMETERS Ordering Information Class Type Description 3020 PM600 Power Meter Module, Basic Instrumentation 3020 PM620 Power Meter Module, Basic Instrumentation, plus Demand, THD, D/T Stamping, Neutral Current 3020 PMD32 Power Meter Display with 1 Foot Cable 3020 SC104 Optional 4 Foot Cable 3020 SC112 Optional 12 Foot Cable 3020 SC130 Optional 30 Foot Cable 11

12 Circuit Monitors Features 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. True rms metering (31st harmonic) Accepts standard CT and PT inputs High accuracy 0.2% current and voltage Over 50 displayed meter values Min/max displays for metered data Power quality readings THD, k-factor, crest factor Harmonic magnitudes and angles through the 31st harmonic Current and voltage sag/swell detection and recording On-board clock/ calendar Easy front panel setup (password protected) RS-485 communications standard Front panel, RS-232 optical communications port standard Modular, field installable analog and digital I/O 1 ms time stamping of status inputs for sequence-of-events recording I/O modules support configurable KYZ pulse output Setpoint controlled alarm/relay functions On-board event and data logging Waveform and event captures, userselectable for 4, 12, 24, 36, 48 or 60 cycles High-speed, triggered event capture Programming language for application specific solutions Downloadable firmware System connections 3-phase, 3-wire delta 3-phase, 4-wire wye Metered or calculated neutral Other metering connections Optional voltage/power module for direct connection to 480 Y/ 277 V Optional Vdc control power Wide operating temperature range ( 25 to 70 C) UL Listed and CSA Certified, CE marking System Highlights Supports multiple PCs Powerful software solutions Easily retrofit 500K Baud, high speed network Programmable controller support Fiber-optic, radio, and modem communications Ethernet interfaces Building automation system compatible MV-90 billing compatible 12

13 Circuit Monitors Comprehensive Metering The POWERLOGIC Circuit Monitor installs on a 3-phase circuit like a conventional watthour meter, but it delivers far more information. In fact, the circuit monitor can replace more than 100 conventional indicating meters. All circuit monitors perform highly accurate, true rms metering. The CM-2050 offers comprehensive metering with 1% accuracy on current and voltage. Models CM-2150 and higher provide 0.2% accuracy on current and voltage, and 0.4% accuracy on power and energy. Protective Functions A circuit monitor equipped with an I/O module can perform certain motor protective functions. These include phase loss, phase reversal, under voltage, and more. Once the circuit monitor detects the abnormal condition, the output relay switches within 1 3 seconds. Each protective function can operate one or more form-c, 10 ampere relays. Each relay can be activated by multiple protective functions. These functions are password protected. Power Quality Readings Total Harmonic Distortion (THD) for current, voltage, and k-factor readings indicate potential power quality problems which, unchecked, could disrupt critical processes or damage equipment. Programming Capabilities The CM-2450 Circuit Monitor is programmed using simple math functions, timers, and compare statements to customize data logging, control functions, and more. For example, you could write a program that logs data by exception rather than at regular intervals, thus maximizing the circuit monitor s memory. Meter values can be analyzed in the circuit monitor and summarized in daily, weekly, and monthly reports. Easy Setup Basic circuit monitor setup can be performed from either the front of the circuit monitor, or a personal computer running POWERLOGIC application software. The PC connects to the circuit monitor using either the system network or an optical communications interface. No thumbwheel or DIP switches are involved; therefore, after installation, setup parameters such as the unit address, CT ratio, PT ratio, and baud rate can be configured without exposing personnel to live conductors. For security, all setup information is password protected. Instrumentation Summary 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. Flexible Communications Optically isolated RS-485 communications connect a network of circuit monitors into a power monitoring and control system. The industrially hardened network communicates at speeds up to 500K Baud. It allows a virtually unlimited number of devices to communicate, including circuit monitors, multiple personal computers, POWERLOGIC trip units for low voltage power circuit breakers, MICROLOGIC solid state circuit breakers, and other compatible devices. Extended Memory Options Circuit monitors provide different amounts of non-volatile memory. For example, the CM-2452 can store more than 180,000 values, including dates and times. The memory can be allocated among an event log, a waveform capture log, an event capture log, and up to 14 data logs. The table on the bottom of page 14 shows a typical example of how the user 13

14 Circuit Monitors might configure the available memory for various models. Alarm/Relay Functions Circuit monitors can detect over 100 alarm situations, including over/under conditions, status input changes, and phase unbalance conditions. Each alarm condition can be set to automatically operate one or more circuit monitor relays. Multiple alarms can be assigned to each relay. Up to three form-c, 10 A mechanical relays and one solid-state output are available. On-Board Alarm/Event Logging When an alarm occurs, the circuit monitor can log the event type, date and time, and the most extreme reading during the pick-up delay. When the alarm condition drops out, the dropout date/time and the most extreme reading during the entire event will be logged. The size of the event log can be user configured. Front Panel Features 1 Six-digit LED display 2 Kilo/mega units LEDs 3 Meter indication LEDs 4 Setup/reset parameters 5 Phase indication LEDs 6 Phase select button 7 Select meter buttons 8 Mode indication LEDs 9 Mode select button 10 Optical communications port More than 50 metered values plus extensive minimum and maximum data can be viewed from the large 6-digit LED display. Data Logging Circuit monitors are available with non-volatile memory for storing meter read-ings at regular intervals. A user can configure the size and structure of up to 14 independent data logs to record metered data at intervals from 1 minute to 24 hours. Each data log entry can contain up to 100 values (including date/time). Models CM-2150 and store up to 5,632 values. Models CM-2350 and store up to 51,200 values. Model CM-2452 stores over 180,000 values. Downloadable Firmware The circuit monitor is designed to take advantage of technological advances. As Square D introduces more powerful versions of each circuit monitor, upgrade kits allow the user to install the new capabilities without changing wiring or hardware. This is possible because the circuit monitor has downloadable firmware. The new firmware is transmitted from a PC into the circuit monitor, using the front optical communications port or the rear RS-485 port. The equipment containing the monitor does not have to be de-energized. This allows you to keep your circuit monitors up to date with the latest enhancements, minimizing the fear of obsolescence. Field Installable I/O Modules Field installable input/output modules provide maximum flexibility, while keeping the costs for an application at a minimum. An I/O module can be easily installed on the back of the circuit monitor. Seven different I/O modules are available. The modules provide various combinations of digital and analog I/O, ranging from 1 digital input and 1 digital output to 4 digital Typical Memory Configuration➀ CM-2050 CM-2150 CM-2250 CM-2350/2450 CM-2452 Event Log N/A 200 Events 200 Events 500 Events 1500 Events 1 Data Log N/A 8 Days 8 Days 40 Days 120 Days Waveform 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 The exact number of waveforms 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 on memory allocation. The CM-2452 can store up to 60 waveform captures, or cycle event captures can be stored in the CM-2350 and -2450, depending on memory allocation. 14

15 Circuit Monitors inputs, 4 digital outputs, 4 analog inputs, and 4 analog outputs. Two inputs and one output perform special functions. Status input S1 can be 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 external relay to trigger the circuit monitor s event capture. The KYZ solid-state output is ideal for pulse initiator applications. The form C, 10 amp mechanical relay outputs are extremely flexible each can be configured for remote (external) or circuit monitor (internal) control. In addition, each output can be configured for normal, latched, timed, or one of six different pulse initiator modes. The analog inputs are field convertible from 0 5 Vdc to 4 20 ma. Waveform Capture Square D pioneered the concept of waveform capture. Circuit monitors use a patented, high-speed sampling technique to sample 64 times per cycle on all current and voltage signals simultaneously. The captured waveforms are stored in the circuit monitor memory for retrieval and display by POW- ERLOGIC application software. Waveform captures are triggered internally or externally. A personal computer can send a signal over the communications POWERLOGIC software can show all phase voltage and current waveforms simultaneously, or a single waveform with a data block containing harmonics through the 31st. network or through the optical communications port. An external signal, for example, from an overcurrent relay, can be received through a high-speed input. The waveform capture can also be triggered internally by any of over 100 user-defined alarm conditions, including high or low power factor, %THD, or phase loss. Sag/Swell Detection The circuit monitor can continuously monitor for sags and swells on any metered voltage or current. This feature can help detect and analyze troublesome voltage disturbances that can cause costly equipment down time. The circuit monitor detects sags and swells based on user-defined setpoints and delays (in cycles). When the circuit monitor detects a voltage or current disturbance, it performs an event capture to record the disturbance. This capture is configurable for 12, 24, 36, 48, or 60 cycles. It is performed using the same patented, 64 samples-per-cycle sampling rate as 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 both before and after the disturbance. The event can be date and time stamped to the millisecond, and recorded in the event log. Mounting Options In addition to the standard flush mounting, several other mounting options are available. For applications requiring an indoor general purpose surface mounted (NEMA 1) enclosure, a 3090 SMA-220 is used. The circuit POWERLOGIC software can display sag/swell data captured by the circuit monitor. This screen shows a voltage sag experienced from a single-phase operation of a recloser. 15

16 Circuit Monitors monitor mounts through the door of the enclosure, providing easy access to the rear of the monitor. The enclosure is deep enough to accommodate options, including I/O modules and voltage power modules. The 3090 SMA-220 (left) and the 3090 CMA-100 provide convenient alternatives to flush panel mounting. For applications where depth in the equipment enclosure is critical, POWERLOGIC provides the 3090 CMA-100 and 3090 CMA-110 adapters. The CMA-100 reduces the depth requirements by extending the circuit monitor beyond the front of the equipment. The CMA110 allows the voltage/power module and some I/O modules to be mounted off of the back of the circuit monitor. Control Power Options In addition to CT and PT inputs, the circuit monitor requires control power. The circuit monitor accepts a wide range of voltages including 120/240 Vac nominal 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. This add-on module eliminates the need for PTs and provides control power. The optional 3090 CPM-48 Control Power Module is used when Vdc is available. A 3090 RTM-317 Ride Through Module is also available which provides backup control power for up to 8 seconds depending on the presence of I/O modules. These modules can be conveniently mounted on the back of a circuit monitor or on a nearby flat surface. To complete the offering, Square D manufactures a complete line of control power transformers. Optical Communications Interface The circuit monitor has an optical communications port built into the front panel as a standard feature. Using this port, a portable computer with an optical communications interface (OCI-2000) can retrieve data from the circuit monitor. The OCI-2000 mounts magnetically to the circuit monitor and provides a standard RS-232 interface. This interface can be used by engineers and maintenance personnel to retrieve captured waveforms, event and data logs, and other information without connecting to the network. An I/O module and either a voltage/power module, a control power module, or a ride through module can mount on the back of the circuit monitor. It s easy to tap into a circuit monitor using a PC and an optical communications interface. 16

17 TYPE 1 ENCLOSURE INDOOR USE ONLY Ic- 3 PHASE VOLTAGE INPUTS 120 VOLTS NOMINAL 3 PHASE CURRENT INPUTS 5 AMPS NOMINAL AUXILIARY CURRENT INPUTS 5 AMPS NOMINAL IN+ IN- OUT+ OUT- SHLD RS-485 DATA COMMUNICATIONS CONTROL POWER 14 VA POWER MONITORING & CONTROL SYSTEMS Circuit Monitors Dimensions Typical Wiring Diagram* AØ BØ Line CØ N CTs (5 Amp Secondaries) VDS Load Kilo Mega o AMMETER (A) o VOLTMETER, L-L (V) o VOLTMETER, L-N (V) o WATTMETER (W) o VARMETER (VAr) o VA METER (VA) [CT Primary] [PT Primary] [Sys. Type] [Dmd. Int.] [WH/Pulse] [Address] 3-PHASE A (A-B) PHASE B (B-C) C (C-A) N Fuses WYE PT CONNECTION (120 V L-N Secondaries) Fuse CPT (120 or 240 Vac Secondary, 14 VA) o POWER FACTOR METER [Baud Rate] o FREQUENCY METER (Hz) [Nom. Freq.] o DEMAND AMMETER (A) [Reset] SELECT METER [Value] o DEMAND POWER (W) [Reset] o DEMAND POWER (VA) [Reset] o WATTHOUR METER [Reset] o VARHOUR METER [Reset] o THD, CURRENT (%) [Rst. Min/Max] o THD, VOLTAGE (%) [Set Password] o K-FACTOR [Accept] Optical Comm Port METERS MIN MAX ALARM [Setup] MODE Fuses Disconnect Switch CIRCUIT MONITOR Vn Vc Vb Va Fuse CT Shorting Block Front View Side View with Modules In- In+ Ic+ Ib- Ib+ Ia- Ia+ (+)L G N(-) True Earth Ground Top View Inches Millimeters * 3-Phase, 4-Wire WYE with optional metered neutral. (3-Wire Delta and other system types supported.) Feature Comparison Feature 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/356k Sag/Swell Detection Programmable for Custom Applications Ordering Information Class Type Description 3020 CM-2050 Instrumentation, 1% accuracy 3020 CM-2150 Instrumentation, 0.2% accuracy, data logging, alarm/relay functions 3020 CM-2250 Waveform capture, plus CM-2150 features 3020 CM-2350 Disturbance monitoring, 100k extended memory, plus CM-2250 features 3020 CM-2450 Programmable for custom applications, plus CM-2350 features 3020 CM k extended memory, plus CM-2450 features 3020 CM-2000U Circuit Monitor firmware upgrade kit 3020 IOM-11 I/O Module: 1 status IN, 1 pulse OUT 3020 IOM-18 I/O Module: 8 status IN, 1 pulse OUT 3020 IOM-44 I/O Module: 4 status IN, 1 pulse OUT, 3 relay OUT 3020 IOM I/O Module: 4 status IN, 1 pulse OUT, 3 relay OUT, 1 analog IN, 1 analog OUT (4-20 ma) 3020 IOM I/O Module: 4 status IN, 1 pulse OUT, 3 relay OUT, 1 analog IN, 1 analog OUT (0-1 ma) 3020 IOM I/O Module: 4 status IN, 1 pulse OUT, 3 relay OUT, 4 analog IN, 4 analog OUT (4-20 ma) 3020 IOM I/O Module: 4 status IN, 1 pulse OUT, 3 relay OUT, 4 analog IN, 4 analog OUT (0-1 ma) 3020 RIO foot I/O shielded ribbon cable extension 3090 OCI-2000 Optical communications interface 3090 VPM-277-C1 Voltage/power module for direct connect to 480Y/277V circuits 3090 CPM-48 Control power module to connect circuit monitors to Vac control power 3090 CMA-110 CM2 mounting adapter with accessory compartment 3090 SMA-220 Circuit Monitor surface mounting enclosure with hinged cover 3090 CMA-100 Circuit Monitor mounting adapter to reduce rear clearance requirements 3090 RTM-317 Ride through module for 17 Watt devices (i.e. circuit monitors) Technical Specifications Metering Specifications Current Inputs (each channel) Current Range A ac Nominal Current... 5 A ac Voltage Inputs (each channel) Voltage Range Vac Nominal Voltage (typical) Vac Freq. Range (50/60 Hz) Hz Freq. Range (400 Hz) Hz Harmonic Response Voltage, Current Freq. 45 Hz 65 Hz... 31st Harmonic Freq. 350 Hz 440 Hz... 3rd Harmonic Accuracy Current... +/- 0.20% Voltage... +/- 0.20% Power... +/- 0.40% Energy... +/- 0.40% Demand... +/- 0.40% Power Factor... +/ Frequency 50/60 Hz... +/ Hz Frequency 400 Hz... +/- 0.5 Hz Control Power Input Specifications Input Range, ac Vac Frequency Range Hz Input Range, dc Vdc Burden VA Temp. Range (operating) to 70 C Accuracies apply to CM-2150, CM-2250, CM-2350, CM-2450 and CM-2452 only. Model CM-2050 meets a 1% accuracy class for current and voltage, and 2% for energy and demand. 17

18 System Manager 3000 Software Features Power information anytime, anywhere Microsoft Windows NT and Flexible Electrical Historical Database Data sharing from centralized open ODBC database Predefined typical billing and power quality logging templates Tabular viewing and trending of standard and user selectable quantities Multiple device quantity comparison on same trend plot Historical data management archival and restoring Real-time Power Management Multilevel network alarming Task execution ( , paging, resets, file uploads, etc.) on schedule or upon alarm detection Pre-engineered real time-data displays tables, bar charts, meter panels Event recording and sorting assist troubleshooting event sequence Integrated Device Support More than 1000 devices supported per POWERLOGIC network server Advanced open support for intelligent, compatible monitoring devices from other manufacturers displaying data, alarming, logging, and manual control Complete online device setup for all Square D supported devices Manual and automatic device resets eliminate redundant steps Manual control and setup of automatic onboard circuit monitor control aid to avoid setting peaks 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. Contextsensitive online help system. Dockable toolbar allows quick access to functions used frequently. Device list allows easy switching between devices displayed. Meter panel scales with window for easy viewing includes alarm setpoint markings. Bar chart type list allows easy switching between bar chart types displayed. Name of online system is displayed for quick reference. System time. Name of system open for editing is displayed. Can be the online system. 18

19 System Manager 3000 Software The System Manager 3000 software (SMS) family and POWERLOGIC Power Monitoring and Control Systems provide a total, integrated system approach to power management. As a result, accessing power information and distributing it wherever it s needed is more easily achieved. Designed primarily for power system engineers, SMS-3000 software brings information from your power system directly to your desktop. The third generation of POWERLOGIC power monitoring software, the SMS-3000 program runs on Microsoft Windows NT and Windows 95 operating systems. The inherent open system and network capabilities of SMS-3000 software help users minimize energy costs, reduce peak demand charges and power factor penalties, and reduce downtime. Whether your power monitoring application requires a single workstation or a full-featured system of networked computers, the new POWERLOGIC SMS-3000 software family offers a variety of functions to make managing and analyzing your power system easier. Scaleable Solution: Client/Server to Stand-alone Client/server applications today are not limited to the computing power of one computer. Instead, they share the workload between multiple computers. With SMS-3000 software, the POWERLOGIC network server handles all device communications, data logging and storage, and alarm management tasks. The SMS-3000 client converts the data it receives from the server into usable formats such as tables, bar charts, and trend plots. It is not necessary for client PCs to be connected to the POWERLOGIC device network; only the POWERLOGIC network server is connected to the device network. SMS-3000 software frees you to position client PCs anywhere on the PC local area network. Client/Server Products System Manager 3000 (SMS-3000) software is the client/server product consisting of one POWERLOGIC network server and one SMS client. The SMS-1000 software product is an additional client application that can be placed wherever it is needed. The client is used with SMS-3000 software via a local area network or wide area network. Stand-alone Products System Manager 1500 (SMS-1500) and Power Monitoring EXPlorer (PMX- 1500) software are stand-alone products with device setup, communication and data displaying capabilities contained on the same PC thus not requiring the PC local area network. SMS-3000 software and SMS-1500 software both support the Interactive Graphics Client. See the back cover for feature comparison between product offerings. Flexibility One of the primary features of client/server technology is flexibility. The System Manager 3000 family allows greater flexibility for power monitoring systems, whether you need a standalone system, multiple POWERLOGIC network servers, multiple clients, remote clients, remote sites, or even a single database to store data from multiple servers. Expand by adding additional clients. Product Descriptions POWERLOGIC APPLICATION SOFTWARE Client/Server Stand-alone Client Only Single Device ADD-ON MODULE Interactive Graphics Limited Limited Full Featured Operating System SMS-3000 Windows NT PMX-1500 SMS-1500 PMX-1000 SMS-1000 SMS-121 Full Featured GFX-1000 Windows NT Windows 95 Windows NT Windows 95 Windows NT Windows 95 Operating System Windows NT Windows 95 Description Client/Server network aware software for power monitoring and control. Includes one SMS client and the POWERLOGIC network server. Self contained stand-alone power monitoring application that does not support networked clients. Additional SMS client to connect to SMS-3000 POWERLOGIC network server. Self contained stand-alone power monitoring application that communicates to one device at a time. Description 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. Compatible With: SMS-3000 SMS-1500 PMX-1500 SMS

20 System Manager 3000 Software POWERLOGIC MMS Ethernet Gateway Stand-alone software allows logging and displaying of information on one PC. Networking is optional. Remote sites can be automatically dialed via model to upload data from the devices. Plant management can monitor entire plant with graphical one line diagram using SMS and GFX-100 from a PC within the office. Accounting can access the database for cost allocation without having SMS client running. SMS-3000 software creates tend plots of logged historical data. You can display historical information for any quantity from any device in the system. Laptop connection via modem to the POWERLOGIC network server for remote alarm acknowledgement. Etherent connection to local area network Maintenance can monitor and acknowledge alarms on POWERLOGIC network server from a remote PC. Security In addition to the security the Microsoft operating system provides, SMS provides security layers of its own, ensuring that your power system data are thoroughly protected. SMS supports unlimited user accounts, each with a unique name and password. In addition, SMS supports privilege access levels that determine which functions each user can access. Auto-Dial In some cases, you may want to monitor power system information in more than one location. SMS-3000 software offers a auto-dial feature designed to dial remote sites on a scheduled basis and automatically upload the system data. This feature lets users monitor sites across campus or selected remote locations. Historical Logging and Trending The POWERLOGIC system is a collection of distributed databases. SMS automatically collects the extremely accurate historical onboard device data logs as well as collecting and storing data for devices without onboard memory into one centralized ODBC-compliant database. The circuit data can be easily retrieved, displayed and printed in standard historical tabular or trend formats. Custom user selectable styles are also available. For example, this provides selectable quantities and different interval logging for 24 hours or during shift hours. Open Database System Manager 3000 software family complies with the Microsoft Open DataBase Connectivity (ODBC) standards of data storage. This ensures that data stored by the POWERLOGIC network server can be formatted for any ODBC-compliant database. SMS-3000 software uses an embedded Microsoft Access database and is fully tested with both Microsoft Access and Microsoft SQL drivers. Other ODBC-compliant drivers can be installed and used if desired. Tasks Tasks can be performed when an alarm condition is detected, or on a scheduled basis. Available tasks include launching executable programs such as paging software packages, soundwave files, device resets, sending electronic mail, uploading onboard device data, and retrieving or capturing a waveform. Scheduled tasks can be executed hourly, daily, weekly, 20

21 System Manager 3000 Software monthly, just once, or at other defined intervals. Control SMS-3000 software supports manual control of relay output contacts. Only users with the appropriate user privilege level can access this feature, avoiding accidental or unauthorized usage. Remote-manual control of operations, such as initiating a start-up or a load shedding shutdown sequence, can be performed through the software. Event Recording SMS uses event recording to track events in your system, from power outages to setup changes to manual control. All system-user actions are logged to the Event Log, which may be viewed, printed, or cleared at any time. The Event Log is sortable by field, including device, date/time, type of event, and user name. This aids in future troubleshooting of your system by showing all information. Functions/Alarms SMS supports software alarms for digital and analog inputs in addition to devices that have onboard alarm/event capabilities. Analog and digital alarm conditions are set up once, then applied to the desired devices and adjusted individually as needed. Conditional logic is also possible when custom 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 separate severity level. When an alarm condition is detected, it is broadcast across the entire SMS-3000 network logged in alarm log, and can initiate automatic tasks on the POWERLOGIC network server PC. Alarm Severity Levels Analog and digital alarm conditions can be set for one of 10 severity levels; each can be set for audible and visible required acknowledgment. Each severity level can also require a password to acknowledge the alarm. You can further customize severity levels by associating a specific color or sound with the level or both. Resets SMS supports various resets for all supported device types. For example, circuit monitor minimums and maximums, peak demand currents, and energy alarms may be reset. You can reset quantities manually or on a scheduled basis, individually, or simultaneously. The date/time of each reset is stored for each quantity in the Event Log. Sixty consecutive cycles of waveform display show swell and two sags. Disturbance Monitoring Harmonics which can lead to increased neutral currents, excessive capacitor currents, or transformer and motor failure can be displayed through the software. POWERLOGIC circuit monitors use a high-speed digital sampling technique to monitor the circuit voltages and currents. Circuit waveforms and harmonic content through the 31st harmonic can be captured and stored for later use. Waveform Analysis Waveform information can also be displayed in a Data Block format, which includes odd and even harmonic magnitudes, crest factors, and percent total harmonic distortion (%THD) as defined in IEEE-519. Waveforms can be further analyzed using waveform analysis software. Current and voltage waveforms can be viewed simultaneously or individually, and can be printed. A data block of harmonic information can also be displayed for 4-cycle waveforms. 21

22 System Manager 3000 Software Easy System Setup Minimal user configuration is required to get a SMS system up and running. Device addresses and a few system and device parameters are all that are necessary. Devices can be set up individually, or by configuring global parameters applied to similar devices. Help System Complete, online, context-sensitive help is available anywhere in the program. The system is categorized, and any topic may be selected or printed. Most setup dialog boxes contain a Help button, which is linked directly to information on that dialog box. SMS-3000 software also supports right mouse button and F1 key functionality. Real-Time Displays SMS supports a variety of real-time data displays, from tables and bar charts to analog meters. SMS-3000 software comes preconfigured with many standard real-time displays to view any of the thousands of device quantities SMS-3000 software offers a variety of predefined and customizable real-time data displays. Printing support Any real-time or historical data that can be displayed in a window or multiple windows may be saved to a disk or printed, either individually or in a report. Groups Selecting devices by function, area, or electrical organization is simplified by the configuration of groups. The group feature allows devices and quantities to be organized logically, each with a unique name. System Manager software can be easily customized by adding new devices and quantities, and creating custom tables like the one shown. Customization SMS is easy to customize, including the ability to create custom tables and add custom quantities. Custom quantities can be any value read from a POWERLOGIC device, a metered value from another utility (gas, water, air, etc.), or a dynamic data exchange (DDE) quantity from another application. Custom Tables New tables can be created through a wizard-type user interface. Simply select multiple devices and the quantity to be displayed, or select a single device with multiple quantities, and the table will be generated. There is also an advanced custom table utility that allows complete user flexibility of the formatting, object embedding, and mathematical manipulation for viewing of a single- or multiple-page table or graph. Dynamic Data Exchange Dynamic data exchange (DDE) is a standard feature of SMS-3000 software. With DDE, the user can serve system data to another application, such as an Excel spreadsheet, for advanced reporting or graphing. In addition, SMS-3000 software can read, display, log, trend, and even alarm via DDE from other applications such as building automation systems or process control systems. Reports System Manager software generates reports using any information, including real-time displays. SMS-3000 software supports standard reports 22

23 System Manager 3000 Software and reports that have been customized. Automatic report generation also is quick and easy. Interactive Graphics The POWERLOGIC Interactive Graphics Client (GFX-1000) is a color graphics client application. It displays system-wide information (one line diagrams, site plans or front elevation drawings) received from the POWERLOGIC network server on Windows Metafile drawings. GFX-1000 can be used with SMS-3000 software or POWERLOGIC stand-alone packages. When used with SMS-3000 software, GFX-1000 can be installed as a separate client on any PC on the local area network. When used with stand-alone systems, GFX must be installed on the same PC. System Requirements The table below lists the minimum system requirements. The specifications in brackets "[ ]" are recommended for superior performance. The hard disk requirements for Windows operating system should also be considered when choosing a computer. The table below details the features available in the System Manager 3000 software product family. Communication User Interface PMX-1000 SMS-1000 SMS-3000 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 SMS-1500 GFX-1000 SMS-121 PMX-1500 Numbering xxx-3000 Client/Server conventions: xxx-1500 Stand-alone xxx-1000 Clients work with SMS-3000 except GFX-1000 works with SMS-3000 and xxx-1500 products 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-3000 PMX-1500 SMS-1500 SMS-121* SMS-1000 PMX-1000 GFX-1000 Windows NT/95 SMS-3000 (Windows NT only) VGA VGA [Super VGA] [Super VGA] 486 / 66 Pentium [Pentium] 32M 16M [32M] 500M 500M 15M optional required required 14.4 or 28.8 (opt.) optional required recommended 8M required optional required recommended The amount of memory required on the hard disk depends on whether the logging data is stored on the same computer. * System Manager One-To-One (SMS-121 software) uses the serial port to communicate, so the SY/LINK requirements listed in the table do not apply. Ordering Information Description Class Type System 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

24 Ethernet Gateway The POWERLOGIC Power Monitoring and Control System offers direct connection to Ethernet-TCP/IP networks to make power monitoring and power quality information available over new and existing local and wide area networks. From a central Features Allows communications with POWERLOGIC compatible devices over standard Ethernet- TCP/IP networks One or two RS-485 serial ports at 19.2K Baud Fully TCP/IP and OSI compliant Standard AUI and RJ-45 Ethernet ports Up to 10 simultaneous logical connections from host device (e.g., SMS-3000) per RS-485 port 120/240Vac, 125Vdc control power On-board security lockout feature (user configurable) Integral 12Vdc AUI control power Small footprint: 4.76 (121)H x 7.25 (184)W x 9.05 (230)D inches (millimeters) Tabletop or wall mounting UL, CSA F (0 60 C) ambient operating temperature Diagnostic LEDs on RS-485 ports and RJ-45 Ethernet port location or many remote locations, you Configuration example of a POWERLOGIC Power Monitoring and Control System using Ethernet can now better manage your electrical distribution system using Ethernet networking technologies as well as the Internet. Configuration example of a POWERLOGIC Power Monitoring and Control System using Ethernet and an industrial area network 24

25 Ethernet Gateway The POWERLOGIC system offers the flexibility to build entire power monitoring and control systems using Ethernet-TCP/IP (Transmission Control Protocol/Internet Protocol) as the high-speed network backbone. POWERLOGIC Ethernet connectivity products consist of a gateway device and an Ethernet driver for the SMS-3000 family of System Manager software products. SMS-3000 power monitoring software operates on Microsoft Windows 95 and Windows NT. The combination of the gateway and driver creates a system with optimal communication performance and accessibility to power system information. Electrical distribution systems now often have hundreds, and even thousands, of communicating devices. A high-speed, high-bandwidth network such as Ethernet often becomes necessary to handle the increased data throughput required. In many cases, an existing Ethernet network can be used to avoid the cost of installing and maintaining a separate backbone network. Ethernet is the most widely supported network in the world. It offers an open architecture, speed, wide range of connectivity products, and virtually unlimited flexibility allowing users to build any size network. These benefits ensure users of their investment in Ethernet as the backbone network of choice for power monitoring and control systems. As your POWERLOGIC system expands (number of users increase, and additional devices are implemented), so too can your network using standard, off-the-shelf products that meet your specific needs. The POWERLOGIC system allows you to leverage existing Ethernet technology for power monitoring, power quality, and other information over virtually any existing communication infrastructure, including the Internet. Improved System Performance The POWERLOGIC Ethernet Gateway and the SMS Ethernet Driver have been engineered to form a tightly coupled system. Together these components form the basis for a reliable, high-speed power monitoring solution. The SMS Ethernet Driver allows simultaneous communication requests to multiple gateways providing faster overall throughput in gathering data from the entire POWERLOGIC system. TCP/IP and OSI Protocols Many Etherent networks are based on TCP/IP. This is the standard protocol for delivering information and is what the Internet and many Intranets use. Other network systems utilize the equally powerful Open Systems Interconnect (OSI) protocol. The System Manager Ethernet Driver and Ethernet Gateway support both TCP/IP and OSI protocols. Either protocol is routable through existing IP routers, hubs, etc., allowing users to select the protocol stack best suited for their application. Manufacturing Message Specification (MMS) The POWERLOGIC Ethernet connectivity solution uses MMS as the messaging protocol over Ethernet. MMS is an international standard (ISO/ IEC 9506) for exchanging real-time data and supervisory information between network devices. As an international standard, MMS is not controlled by any one entity. Overall, MMS provides a very powerful, high throughput platform for network communication. MMS offers increased flexibility in integrating other devices and systems into a POWERLOGIC system. The messaging services provided by MMS are broad enough to cover a wide range of applications while the MMS protocol itself is independent of the application being performed. 25

26 Ethernet Gateway Easy Configuration Both the System Manager Ethernet driver and gateway are easily configured and secured. Standard dialog box setup screens for communicating with the gateway reside in System Manager. The gateway has an onboard setup utility that is easily configured via the RS-232 port using a standard terminal emulator software program, such as Windows Terminal. The setup utility contains all configuration parameters for the gateway as well as diagnostic parameters. Additionally, an extensive help system is included in the setup utility. All configuration information is stored in nonvolatile memory and therefore, not affected on loss of control power. Gateway and Network Integrity Each serial port contains RS-485 biasing and surge protection circuitry to ensure reliable operation where noise may be present from nonlinear devices, electromagnetic induced equipment, or single capacitive coupling of the power system voltages. Easy Field Upgrades As features are added to the system components either in System Manager, the gateway, or the end devices the gateway can be easily updated via the RS-232 port. This firmware upgrade is accomplished without hardware replacement, lengthy system downtime, or system reconfiguration. Support for Existing POWERLOGIC Systems The POWERLOGIC Ethernet Gateway supports routing into existing SY/NET network based systems. The RS-485 ports on the gateway can be connected to another RS-485 port on the network interface module (NIM, PNIM, etc.) making information from the SY/NET network available over Ethernet. This approach benefits existing facilities where POWERLOGIC systems are already in use. Users of existing Square D networks can choose to augment their systems by using Ethernet as the high-speed backbone. System Manager and Client/Server System System Manager 3000 software uses client/server technology for managing activity and information on the Ethernet network. This is ideal for systems where multiple users need access to power system information. The POWERLOGIC Network Server, which may be a dedicated Windows NT workstation or any one of the user s personal computers, serves requested information to users elsewhere on the network running System Manager client software. This provides many users access to the information for various functions such as energy cost accounting, power The POWERLOGIC Ethernet Gateway combined with System Manager software brings power system information to any personal computer on the local area network or even the Internet. quality monitoring, or maintenance activities. All users share a common historical database through Microsoft s Open Database Connectivity (ODBC) standard. The ODBC standard is supported by a wide variety of software vendors as an open solution. 26

27 Ethernet Gateway INCHES MILLIMETERS Ethernet Gateway Dimensions Overhead mounting Technical Specifications Control Power Input Specifications Input Range, ac Vac Frequency... 50/60 Hz Input Range, dc Vdc Burden... Up to 72 VA Environmental Specifications Ambient Operating Temperature to 140 F (0 to 60 C) Ambient Storage Temperature to 176 F (-40 to 85 C) Relative Humidity Rating (noncondensing)... 5 to 95% Regulatory/Standards Compliance UL Listed, CSA Certified Minumum PC Requirements for System Manager 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 Left-side mounting Right-side mounting Optional Ethernet Gateway Mounting Brackets Ordering Information Class Type Description 3050 EGW1 POWERLOGIC Ethernet Gateway with (1) RS-485 port (up to 8 devices) 3050 EGW2 POWERLOGIC Ethernet Gateway with (2) RS-485 ports (up to 128 devices) 3050 EGWMBK Mounting Brackets Kit 3050 EGWNMC Null Modem Cable 3080 TCPMMS POWERLOGIC Ethernet Driver for SMS-3000 Software family. 27

28 Digital Relay The POWERLOGIC system is a family of power monitoring and control products that provides comprehensive solutions for Features 3-phase and ground overcurrent protection User-selectable time current curves Local keypad and display of metering and settings POWERLOGIC system compatible Remote monitoring using System Manager software Optional latching of output relay contacts (ANSI 86) Self-diagnostics for improved reliability Trip and self-diagnostic indicators High level of immunity to electromagnetic disturbances Status input for remote indication of circuit breaker position Removable terminal blocks for ease of maintenance Supports 1 A or 5 A phase CT inputs Zero sequence current determined by 3-phase internal summation Optional support of CSH zero sequence toroids for external sensing of ground fault currents 120 Vac or 48/125 Vdc control power options power distribution Ethernet High-Speed LAN system management. The POWERLOGIC system can help improve system reliability, lower Main DR CM EGW Legend DR CM EGW LAN PowerLogic Digital Relay (50/51 and 50N/51N) PowerLogic Circuit Monitor PowerLogic Ethernet Gateway Local Area Network 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. Feeders DR DR DR DR Typical medium voltage switchgear lineup one line diagram. 28

29 Digital Relay Protection and Flexibility The POWERLOGIC digital relay accepts current inputs from standard 1- ampere or 5-ampere current transformers, and is suitable for a wide range of applications on medium voltage circuits. Time-current characteristics are independently adjustable for phase and ground from a variety of curve shapes inverse, very inverse, extremely inverse, and so on. Close tolerances on programmable relay pickup settings and flexible time delay adjustments permit better coordination with upstream and downstream devices. Curve shapes, current transformer (CT) ratios, and relay settings are set using the simple front-panel keypad and display. The digital relay provides a variety of metering and status information, and supports various capabilities from a remote PC phase Overcurrent (ANSI 50/51) The digital relay senses overloads and short circuits between phases, and initiates a breaker trip. The relay has both time overcurrent and instantaneous pickup settings. When a current exceeds one of these settings, the digital 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 breaker trip. The relay has both time overcurrent and instantaneous pickup settings. When a current exceeds one of these settings, the relay displays a GND FAULT message. After the relay operates, its red trip LED flashes, indicating that a trip has occurred. UIT Curve The digital relay features a new type of inverse-time-overcurrent curve known as the ultra inverse time curve (UIT). This unique curve provides better coordination with fuses and devices that require extreme coordination. Time Overcurrent Settings The digital relay has three settings for time overcurrent: time current curve, current setting, and time delay. Time current curves are divided into two categories: definite time and inverse-time-overcurrent. For the definite time curve and the RI curve, the current setting is the tripping pickup. Instantaneous Pickup Settings The digital relay has two settings for instantaneous protection: instantaneous pickup and instantaneous time delay. Ammeter The digital relay displays instantaneous phase ammeter readings and phase block demand ammeter readings on the LCD display. By equipping the digital relay with optional communications, the following values can be viewed 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 actual primary values in A, ka, and seconds On indicator light Lights when the digital relay is energized. Self-diagnostic indicator Lights if an internal failure occurs. Trip indicator Lights when the digital relay operates a circuit breaker after detecting an overcurrent. A trip message on the display indicates the type of overcurrent. 16--character LCD display Displays the following: Phase ammeter readings Phase demand ammeter readings Phase/ground amperes at time of last trip All setup values Messages Keyboard Use these buttons to advance through the digital relay display menus. 29

30 Digital Relay Event History Information The digital relay provides two types of historical information: trip history and pickup history. The current values at the time of the last trip can be viewed on the LCD display. A more detailed trip history for the last three trips can be 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 the last pickup for time overcurrent and instantaneous overcurrent, for both phase and ground. Continuous Self Diagnostics The digital relay continually monitors the analog-to-digital conversion channel, the microprocessor, the memory components, the internal voltage supply, the integrity of its values, and the internal software program. If the digital relay detects an internal failure, it inhibits the output relay contacts and operates a watchdog output relay. The watchdog output relay contacts can be connected to an alarm, such as a light or bell, to indicate that an internal failure has occurred. For digital relays with communications, the diagnostic status can be viewed on a remote PC. This self-diagnostic feature makes the digital relay more reliable than an electromechanical relay; in electromechanical relays, internal failures can only be detected by periodic manual tests. POWERLOGIC Compatible The digital relay is compatible with POWERLOGIC systems; therefore, it is supported by POWERLOGIC software. The relay can share an RS-485 communications link with circuit monitors operating at a baud rate from 1200 to 19,200 bps. Digital relays can be daisy-chained with up to 32 POWERLOGIC devices over a 10,000 foot (3050 meter) span. Communications Capabilities Communicating versions of the digital relay have remote capabilities such as status monitoring, metering, relay reset, and circuit breaker operations. The digital relay has one status input that can be used for remote status monitoring; for example, indicating circuit breaker position. In addition, remote phase and ground current metering, trip event history, and data logging can be performed using POWERLOGIC software. Remote relay resets and remote circuit breaker operations can also be performed over the communications network. 30 POWERLOGIC application software configured to display realtime phase and ground currents, circuit breaker status, and trip history in an easy-to-read, graphic format.

31 Digital Relay Time Characteristic Curves 1000 Ultra Inverse Time Extremely Inverse Time Very Inverse Time UIT EIT VIT T i m e i n s e c o n d s T i m e i n s e c o n d s T i m e i n s e c o n d s Current in multiples of pickup (I/PHCS or I/GFCS) Current in multiples of pickup (I/PHCS or I/GFCS) Current in multiples of pickup (I/PHCS or I/GFCS) Standard Inverse Time SIT 1000 Rapid Inverse RI 100 Definite Time DT 90s T i m e i n s e c o n d s T i m e i n s e c o n d s Adjustable T i m e i n s e c o n d s Current in multiples of pickup (I/PHCS or I/GFCS) Current in multiples of pickup (I/PHCS or I/GFCS) Current in multiples of pickup (I/PHCS or I/GFCS)

32 Digital Relay Parameter 3-Phase Overcurrent Parameter Settings Settings CT Primary Rated Current (PH CT) A: ka: Curve (PH TCC) DT - SIT - VIT - EIT - UIT - RI Current Setting (PH CS in multiples of PH CT) 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: s: For all inverse-time-overcurrent curves, the PH TD maximum setting is 12.5 s. Instantaneous Pickup (PH IP in multiples of PH CT) 24 - off Instantaneous Time Delay (PH ITD) inst. : instantaneous, typical tripping time 25 ms. ms: s: 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: with interposing CSH ka: Curve (GF TCC) DT - SIT - VIT - EIT - UIT - RI Current Setting (GF CS in multiples of GF CT) off For all inverse time overcurrent curves, the GF CS setting range is limited to 1.0 x GF CT. Time Delay (GF TD) ms: s: For all inverse-time-overcurrent curves, the GF TD maximum setting is 12.5 s. Instantaneous Pickup (GF IP in multiples of off GF CT) GF ITD inst. : instantaneous, typical tripping time 25 ms. ms: s:

33 Digital Relay Electrical Specifications Phase Current Inputs Burden 1 A CT configuration... <0.001 VA 5 A CT configuration... <0.025 VA CT primary ratings10... A 6250 A Status Input Voltage range Vac/Vdc Input current draw (max.) V; V Must turn off voltage (max.) Vac/Vdc Must turn on voltage (min.) Vac/Vdc Relay Output Contacts (01) Rated current Vdc; Vdc/Vac Breaking capacity dc resistive load Vdc; Vdc/Vac ac resistive load Vdc/Vac Relay Output Contacts (02, 03, 04, 05) Rated current Vdc; Vdc/Vac Breaking capacity dc resistive load Vdc; Vdc/Vac ac resistive load Vdc/Vac Control Power Inputs Voltage Vac Voltage range... 10, +20% Burden VA Inrush current... <18 A for 10 ms Operating frequency Hz Voltage Vdc Voltage range... ±20% Burden W Inrush current... <12 A for 10 ms Regulatory/Standards Compliance Safety... UL 508 Environmental Operating temp ➀.... IEC 68-2 ( 5 to +55 C) Storage temp to +70 C Humidity... 95%, 40 C Electromagnetic Radiated emissions... FCC Part 15 (Class A) Conducted emissions... FCC Part 15 (Class A) RF immunity... IEC (Class III) Electrostatic discharge... IEC (Class III) Electrical 1.2/50 µs impulse withstand... IEC (2 kv for 1 min.) Damped 1 MHz sine wave... IEC (Class III) 5 ns fast transients... IEC (Class IV) Immunity to surge... IEC Dielectric withstand... IEC255-4 (2 kv for 1 min.); UL 508 ➀ Ambient cubicle temperature. Relay components maximum operating temperature is 70 C. Dimensions Side View Panel Cutout Top View Ordering Information Model Number DR-LX S01 X0A TEN DR-LX S01 X0A TBN DR-LX S01 S0A TEN DR-LX S01 S0A TBN CSH 30 CSH 120 CSH Typical Wiring Diagram P AS A B Trip Relay Contacts N L 120 Vac Watchdog Output Relay Contacts Inches Millimeters Standard Phase Current Sensing Connections CCA 650 Phase Current Sensor Module Description Digital overcurrent protective relay (3-phase and ground), 120 Vac control power* Digital overcurrent protective relay (3-phase and ground), 48/125 Vdc control power Digital overcurrent protective relay (3-phase and ground) with data communications, 120 Vac control power* Digital overcurrent protective relay (3-phase and ground) with data communications, 48/125 Vdc control power CSH 30 core balance CT ground fault sensor CSH 120 core balance CT ground fault sensor CSH 200 core balance CT ground fault sensor *Reliable 120Vac control power is required for proper operation. 33

34 MICROLOGIC Circuit Breaker Interface Features 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 at trip Number of overload trips Number of short circuit trips Number of ground fault trips 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 34

35 SFU SE FU 66 L POWER MONITORING & CONTROL SYSTEMS MICROLOGIC Circuit Breaker Interface The POWELOGIC product interface (PIF-3) for MICROLOGIC circuit breakers, 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 trip data and breaker and breaker data from MICROLOGIC full function circuit breakers. The product interface can be mounted in QED switchboards to enable local and remote monitoring of circuit breaker data. The data from up to 32 circuit breakers can be displayed using a POWERLOGIC system display for circuit breakers, or an IBM PC compatible personal computer equipped with System Manager software. Product Interface Mounts Easily in Switchboards The product interface mounts easily in Square D I-Line panelboards and QED switchboards. In new equipment, any MICROLOGIC full function circuit breaker can communicate to the product interface. The Right Connections The product interface provides eight removable terminal plugs for connection of up to eight MICROLOGIC circuit breakers. Each MICROLOGIC circuit breaker is wired to a communications adapter (CIM3F). Each communications adapter is then connected to the terminal strip on the side of the product interface. A removable RS-485 terminal plug is used to daisy-chain the product interface to other POWERLOGIC compatible devices. Technical Specifications Communications... (1) RS-485, (8) MICROLOGIC connectors Clock/calendar accuracy... +/-4 seconds in 24 hours (@25 C) Electrical Control power input Nominal voltage Vac Operating range Vac Burden Vac (132 VA) Frequency range to 65.0 Hz Isolation V, 1 minute Ride through on power loss Vac Fusing... 2 A 250 V slow blow +12 V LED... Indicates +12 V power supply OK +5 V LED... Indicates +5 V power supply OK Battery low LED... When ON, indicates low battery voltage Environmental Operating temperature... 0 to 70 C Storage temperature to +85 C Humidity rating... 95% RH maximum non-condensing RS485 Communications to other devices R Product Interface Side View Communications Terminal Strip Ground Terminal Control Power Fuse Control Power Terminal Strip FUSE AC 250V, 2 AMP 40 G N AC E FUSE DC + - DC IN+ IN- OUT+ OUT- SHLD GND +12V D- D+ GND +12V D- D+ GND +12V D- D+ GND +12V D- D+ GND +12V D- D+ GND +12V D- D+ GND +12V D- D+ GND +12V D- D+ RS485 COMMS ADD + 0 ADD + 1 ADD + 2 ADD + 3 ADD + 4 ADD + 5 ADD + 6 ADD + 7 MICROLOGIC CIRCUIT BREAKERS 12V OK BATTERY LOW 5V OK MADE IN USA Product Interface for Micrologic Circuit Breakers Communications Adapters (CIM3F) 1 required for each Circuit Breaker To Micrologic Circuit Breakers (Up to eight per PIF-3) The product interface can communicate to up to eight MICROLOGIC circuit breakers. Ordering Information Class Type Description 3050 PIF-3 Product Interface for MICROLOGIC Circuit Breakers* * One Multipoint Communciations Adapter (3090 MCA-485) and one Multipoint Communications Terminator (3090 MCT-485) required per RS-485 communications link. 35

36 LIFE-GARD Model 85A Temperature Controller Interface Features Instantaneous readings Temperature, Coil A Temperature, Coil B Temperature, Coil C Temperature, hottest coil Setpoints Fans on Fans off Alarm on Alarm off Shutdown Status Fan mode (auto/ manual) Fan relay (on/off) High temperature alarm relay (normal/setpoint exceeded) Emergency shutdown relay (normal/setpoint exceeded) Transformer type PIF3 PIF85 CM PIF85 CB CB M85A M85A CB PIF-85 interface and other POWERLOGIC devices in a typical POWERLOGIC system 36

37 LIFE-GARD Model 85A Temperature Controller Interface The POWELOGIC product interface for LIFE-GARD Model 85A temperature controllers brings remote transformer temperature monitoring to the POWERLOGIC system. Any Square D PowerCast or conventional dry type transformer, equipped with a LIFE-GARD Model 85A temperature controller can be monitored for temperature and status. The collected data can be displayed and alarmed upon at a remote personal computer using System Manager software. The product interface connects to the Model 85A temperature controller using standard RS-422 communications. The product interface can be located up to 4,000 feet from the Model 85A temperature controller. The product interface provides standard RS-485 communications for connection to the POWERLOGIC communications link. Multiple product interfaces and other POWERLOGIC devices can be daisy-chained to a remote personal computer. The product interface is housed in a steel case designed to be mounted in power equipment. The compact product interface mounts in low-voltage switchboards and other small faces. The wiring connections for communications cables and control power are made to removable terminal plugs on the front of the product interface. Technical Specifications Communications... (1) RS-485 (POWERLOGIC), (1) RS-422 (Model 85A) Clock/calendar accuracy... +/-1.5 seconds in 24 hours (@25 C) Electrical Control power input Nominal voltage Vac Operating range Vac Burden Vac (132 VA) Frequency range... 50/60 Hz Isolation V, 1 minute Ride through on power loss ms Surge suppression Joules DC OK LED... When lit, indicates DC power OK RS-422 COMMS LED... Flashes when RS-422 comms active RS-485 COMMS LED... Flashes when RS-485 comms active Environmental Operating temperature... 0 to 70 C Storage temperature to +85 C Humidity rating... 95% RH maximum non-condensing Physical Weight (approx.)... 3 lbs ADDRESS Address Switches ADDRESS RS-485 DATA COMMS RS-422 TO M85 IN+ IN- OUT+ OUT- SHIELD BAUD XFMR 5 TYPE RESET DC OK L N GND 120 VAC CONTROL POWER 0 RS-422 COMMS RS-422 Terminals for Connection To Model RS-485 Terminals for Connection to PowerLogic Communications Link RS-485 DATA COMMS RS-422 TO M85 IN+ IN- OUT+ OUT- SHIELD BAUD XFMR 5 TYPE RESET DC OK L N GND 120 VAC CONTROL POWER Baud Rate Switch Control Power Transformer Type Switch Disconnect Reset Switch L Control Power Connections 120 VAC N G RS-485 COMMS Inches Millimeters RS-422 COMMS Indicating LEDs RS-485 COMMS Product interface front view Ordering Information Class Type Description 3050 PIF-85 Product Interface for LIFE-GARD Model 85A Temperature Controllers 37

38 Power Management Services Features System design and bill of material recommendations Remote power switching system design Develop specifications, drawings, documentation Automatic control systems/plc ladder programming, including load shed/peak shaving schemes Custom hardware/ software solutions Third party communications interfaces Configured workstations, user software interfaces On-site installation assistance, component configuration and startup Metering connection vertification/testing On-site and headquarters-based customer training Troubleshooting assistance, support for hardware and software products Product upgrades Project coordination Power Management Services provides a complete range of design and operational services including specifying, developing, installing, commissioning, supporting and training users of power monitoring and control systems and remote power switching systems. Engineers maintain expertise in many areas such as communications, personal computers, protective relaying, automatic control systems, and programmable controllers. POWERLOGIC Workstations Square D offers a complete systems approach to power monitoring. POWERLOGIC Application and Engineering provides POWERLOGIC workstations tested and approved personal computers completely configured based on the individual system requirements. POWERLOGIC workstations are designed to handle large amounts of system information, and provide it to those who need it, when they need it. Workstations placed in key locations allow plant engineers, operators, maintenance personnel, and others to make informed decisions using real-time and historical information. PM&CS Technical Support There are several ways to receive top quality support on POWERLOGIC and POWERLINK products; Phone: Fax: BBS: [email protected] D-Fax: (PM&CS Index is Document #104) 38

39 Power Management Services POWERLOGIC University POWERLOGIC University is a series of training courses designed to improve your power management skills. The university focuses on how to install, use, and maintain your POWERLOGIC systems, and how to get the maximum value from them. The university also gives you an understanding of power, associated terminology, and value of the data the POWERLOGIC system and products provide. The university provides you with the tools you will need to get the most out of your POWERLOGIC system. Courses are taught at the POWERLOGIC headquarters in LaVergne, TN and regionally. The university offers courses to certify individuals in installing and maintaining POWERLOGIC systems. These courses are geared toward the installer, and provide all the necessary knowledge to mount and set up the hardware, install the software, set up and configure communications, and download firmware. Certification also provides you with the required software tools to fully maintain and test the system. The university also offers a series of customer training courses designed to improve your skills with the POWERLOGIC system and associated devices. Customers may attend one or all courses. After each course, a certificate of completion is given, and credits toward a POWERLOGIC Expert degree are 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 realize that time is valuable. Therefore, correspondence courses are also available. Receive the course materials and a test which you complete at your convenience and mail back to receive your certificate and credits for the course. An additional option is customer-site training. Any of the POWERLOGIC courses can be conducted at your facility. Courses are also be tailored to meet your specific training needs. Engineers, maintenance technicians, electricians, operators, facilities managers, and others involved in managing a facility s electrical power consumption will benefit from POWERLOGIC university. The curriculum is specifically designed for the end user and installer. For contractors and consultants, the curriculum gives you an expert understanding of the POWERLOGIC system, allowing you to better serve your customers. After attending the university, you will be able to specify and install power equipment correctly. If you obtain product line certification, you will be added to our published list of certified servicing companies. After becoming a POWERLOGIC system expert, contractors and consultants can train their end users. For course descriptions and schedules contact your local sales office or call (615) and ask for the POWERLOGIC University Training Administrator. 39

40 Power Management Services PQ/EM Consulting Features Engineering studies Power system checkups Service reliability improvements Harmonic studies Power quality and energy management Power system data analysis Monitoring services On site measurement Remote measurement Power system disturbance reports Power management reports Energy use baselines Technical seminars Power quality Power management Power system monitoring and data interpretation Energy auditing Your site or ours Benefits of Engineering solutions for your power management problems Square D offers engineering services to solve power management problems in industrial, commercial, utility and institutional facilities. Power Management Services includes solving electric power problems, monitoring power system parameters, training power system users, and cost justification for managers. Registered professional engineers with utility and facility experience identify cost-effective solutions, whether or not the facility is equipped with POWERLOGIC power monitoring and control systems or other Square D systems. Square D provides fully-engineered system solutions to your power management problems. Power Management Services include Solving power quality problems Recommending power system improvements Optimizing equipment efficiency Sample Power Management Issues Harmonic Distortion - Power systems can absorb a surprising amount of harmonic currents without adverse effects. However, when harmonics become excessive they can lead to production shutdowns, equipment failure, and component overloading. Power factor correction capacitors are particularly susceptible to harmonic distortion problems. POWERLOGIC circuit monitor waveform capture shows high levels of current and voltage harmonic distortion. Reducing energy costs Improving service reliability Eliminating production shutdowns Harmonic distortion decreases the transformer capacity to the point that its true capacity is exceeded for several hours each day. 40

41 Power Management Services PQ/EM Consulting Energy Costs - Like power quality, successful electricity cost reduction requires more than just power system data. Here, an industrial plant collected data from their chiller system, but neglected to analyze its implications. Using this data, chiller operating problems and excessive costs were traced to fouled tubes. Remote Monitoring - Collecting information from remote locations can be difficult. Square D can collect power system data via telephone lines, analyze problems, and produce power quality and power management reports. These reports can be faxed to your desk, or transferred to your computer for cutting and pasting into your weekly production report. Voltage Sags - Sags usually occur due to problems on the utility system feeding your facility. Often it is difficult to distinguish between sags and interruptions based on equipment effects alone. Sag solutions may be far less expensive, however, than solutions to interruptions, so it is important to capture each event. This data can also be used to pinpoint problems inside the facility or on the utility system. Energy Management - Electricity costs are difficult to reduce when you do not know where the energy is being used. Power Management Services engineers can help you produce a facility energy profile which identifies energy consumers, measures their contribution to peak demand, and recommends no-cost/low-cost methods to reduce costs. Wiring and Grounding - Many power-related problems occur because basic wiring and grounding practices are overlooked or allowed to deteriorate. In other instances, recommended power schemes are defeated, allowing vacuum cleaners to be plugged into isolated ground circuits and frequently-started induction motors to be served from the same transformer as sensitive computer supplies. 41

42 Year 2000 Compliance HARDWARE Power Meters PM-600, PM-620 Circuit Monitors 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 Digital Relay DR-LX S01 X0A TBN DR-LX S01 X0A TEN DR-LX S01 S0A TBN DR-LX S01 S0A TEN Transformer Temp Interface PIF-85 MICROLOGIC Breaker Interface PIF-3 DS Breaker Trip Unit 810D System Manager 3000 v3.02 System Manager EXPlorer Com SYSTEM SOFTWARE SMS-3000 SMS-1500 PMX-1500 SMS-1000 PMX-1000 GFX-1000 SMS-121 SMS-700 SMS-770 SMS-121 (v2.23 or earlier) EXP-500 EXP-550 PSW-101 Yes Yes Yes Yes Yes Yes Yes Windows Platform (Windows NT 3.51 and above) Windows NT Comments Yes, when used with SMS-3000 v3.02 or later only. Windows 95 or Windows NT Windows 95 or Windows NT Windows 95 or Windows NT Windows 95 or Windows NT Windows 95 or Windows NT Windows 95 or Windows NT Windows 3.1 Windows 3.1 Windows 3.1 Windows 3.1 Windows 3.1 DOS Yes Square D Power Management Operation has evaluated and tested all necessary POWERLOGIC products for proper handling of the Year 2000 transition from December 31, 1999 to January 1, Test criteria also included a leap year test for February 29, The following tables indicate test results for those devices and, where necessary, solutions to help ensure a successful Year 2000 transition. This information is subject to change as additional development and testing occurs. POWERLOGIC Power Monitoring and Control System Hardware Evaluation The internal clock incorporated in hardware devices has been designed to account for the Year 2000 transition. The table at the left shows the test results for POWERLOGIC hardware utilizing an internal clock. Software Evaluation System Manager 3000 software products have been designed to operate as intended for their anticipated useful life, with special design consideration given to proper handling of the Year 2000 transition. The SMS-3000 products in the table at the right have been tested to verify that the intended performance of these software products continues through the Year 2000 transition and for a period of time exceeding the anticipated useful life of these products. Portions of EXPlorer, System Manager and communications software (EXP-500, EXP-550, SMS-700, SMS-770, SMS-121 for Windows 3.1 and PSW-101) will work past the Year 2000 date. However, since the software was developed for operating systems such as Windows 3.1 and earlier versions of DOS, some of the time stamping portions will not work. The known problem areas are history logging, waveform capture and exporting files. Upgrading to the SMS-3000 software family will be necessary if these functions are being implemented in Comments your application. Contact your local Square D sales representative for upgrade pricing. Refer to the table at the left for software selection. History logging, waveform capture and exporting files affected. Upgrade to SMS-1500 or SMS History logging, waveform capture and exporting files affected. Upgrade to SMS-1500 or SMS History logging, waveform capture and exporting files affected. Upgrade to SMS-121 v3.02 or SMS History logging and exporting files affected. Upgrade to PMX-1500 or SMS History logging, waveform capture and exporting files affected. Upgrade to PMX-1500 or SMS History logging affected. Upgrade to SMS-1500 or PMX POWERLOGIC Product Upgrades Square D periodically offers upgrades of device and system software. In order to maximize the benefits of the POWERLOGIC Power Monitoring and Control System, and to take full advantage of design improvements, Square D recommends that users upgrade and maintain their systems by taking full advantage of its upgrade offers for the latest version of firmware and software. 42

43 Suggested System Specifications SECTION 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 specification. The system is defined to include, but not be limited to, remote devices for monitoring, control and protection, device communication interface hardware, inter-communication wiring, personal computer workstations, software, printer where specified, and ancillary equipment. B. The manufacturer shall demonstrate the system is not a prototype and that similar systems have been field installed and successfully operated for at least five years. The PMCS vendor shall have full responsibility for insuring that the PMCS system performs as specified. C. The PMCS shall utilize Ethernet as the high-speed backbone network that supports direct connection of an unlimited number of personal computer workstations anywhere on the network. D. Each Personal Computer Workstation (PCW) connected to the network shall have equal access to information provided by the power monitoring devices for centralizing data display, data logging, alarming, event recording, and other power monitoring operations. Each PCW shall be independent of the other PCWs with its own software to allow the user to retrieve and configure the information based on the user s needs. E. The high-speed network shall allow direct access to data provided by the power monitoring devices for implementing automatic control. F. Application software for personal computer workstations shall be provided as described in Article 2.11 of this specification. G. The PMCS shall be POWERLOGIC as manufactured by Square D Company [or approved equal]. H. All products shall not violate any U. S. patents REFERENCES A. All Power Meters and Circuit Monitors shall be UL 508 Listed, CSA approved, and have CE marking. B. The system shall comply with the applicable portions of NEMA standards. In addition, the control unit shall comply with FCC Emission Standards specified in Part 15, Sub-part J for Class A application SUBMITTALS A. Indicate electrical characteristics and connection requirements. When PMCS components are installed by the power equipment manufacturer, the power equipment shop drawings shall clearly identify the components, the internal connections, and all contractor connections. The PMCS drawings shall show all PMCS components including necessary component dimensions; type, size, and weight; location of conduit entry and exit; single line diagram indicating external wiring requirements. Drawings shall identify terminal blocks used for interconnections and wire type to be used. B. Product Data: Provide catalog sheets and technical data sheets to indicate physical data and electrical performance, electrical characteristics, and connection requirements. 43

44 Suggested System Specifications 1.04 QUALITY A. The PMCS vendor shall be ISO 9000 registered to demonstrate quality compliance. B. PMCS components included within the power equipment lineups shall be factory installed, wired and tested prior to shipment to the job site SYSTEM START-UP AND TRAINING A. On-site start-up and training of the PMCS shall be included in the project bid. B. Start-up shall include a complete working demonstration of the PMCS with simulation of possible operating conditions which may be encountered. C. Training shall include any documentation and hands-on exercises necessary to enable electrical operations personnel to assume full operating responsibility for the PMCS after completion of the training period. 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 factory training for customers on all aspects of power monitoring and control, including: 1. Comprehensive software and hardware setup, configuration, and operation 2. Advanced monitoring and data reporting 3. Advanced power quality and disturbance monitoring F. The power monitoring manufacturer shall provide a full time telephone technical help center for customers. PART 2 PRODUCT 2.01 POWER METERS A. The information provided by the Power Meter shall include the following quantities: 1. Current, per-phase & neutral 2. Volts, phase-to-phase & phase-neutral 3. Real Power (kw), per phase & three-phase total 4. Reactive Power (kvar), per phase & three phase total 5. Apparent Power (kva), per phase & three phase total 6. Power Factor (true), per-phase & three-phase total 7. Frequency 8. Demand Current, per-phase & neutral, present & peak 9. Real Power Demand (kwd), three phase total, present & peak 10. Reactive Power Demand (kvard), three phase total, present & peak 11. Apparent Power Demand (kvad), three phase total, present & peak 12. Real Energy (kwh), three phase total 13. Reactive Energy (kvarh), three phase total 14. Apparent Energy (kvah), three phase total 15. Energy Accumulation modes, signed, absolute, energy in, energy out 16. Total Harmonic Distortion (THD), voltage & current, per phase 17. 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% of full scale for voltage and current sensing, and 0.5% of reading plus 0.05% of full scale for power and energy, accurate through the 31st harmonic. 44

45 Suggested System Specifications 1. These accuracies shall be maintained for both light and full loads. 2. No annual recalibration by users shall be required to maintain these accuracies. 3. Voltage and current for all phases shall be sampled simultaneously to 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 , , series of electrical tests (level 4), FCC compliant per FCC Part 15, Class A, and vibration and temperature tested. The meter module shall be rated for an operating temperature range of 0 C to 60 C. D. The Power Meter metering inputs shall utilize current transformers for the current inputs. It shall be rated 5A nominal and 10A full scale. In addition, it shall be industrially and utility hardened to have an overload withstand rating of 15A continuous and 500A for 1 second. E. The device shall not require potential transformers or control power transformers when applied at 600V or less. The power meter shall accept control power over a range of Vac, 50 or 60 HZ, or Vdc. F. Each Power Meter shall have built-in RS-485 data communications to allow multipoint communication to multiple computer workstations, programmable controllers, and other host devices, up to a data rate of 19,200 baud. G. All information shall be available from the display or via RS-485 communications. It shall be possible to perform the setup via the display. No dip switches or other hardware adjustments shall be required for setup. H. The power meter shall be installed as part of a power monitoring and control system as indicated on the drawings. The RS-485 communications 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 a Modbus-compatible port. 2. The Jbus protocol and connect to any host devices with a J-bus compatible port. 3. The POWERLOGIC protocol and shall connect to any host devices with a POWERLOGIC compatible port. 4. The three protocols mentioned above shall reside in the meter from the factory and be field selectable as part of setup. J. The data communications shall be optically isolated to provide reliable operation. K. When connected via the network to a POWERLOGIC computer, the power meter shall provide logging, trending, and alarming information. L. Each Power Meter shall be equipped with a two-line LCD display as indicated on the project drawings. M. To facilitate ease in mounting, the display shall be capable of being mounted up to 50 feet (15 meters) from the metering module using RJ- 11 terminated communications cable. Regardless of mounting configuration, the display shall always be optically isolated from the power meter module. N. The display shall scale readings automatically, without the need for multipliers. O. All setup information and reset commands shall be password protected. P. A KYZ pulse initiator for communication of kwh, kvarh, or kvah information to third-party energy management systems shall be pro- 45

46 Suggested System Specifications vided. Q. The power meter shall provide diagnostics to trouble shoot miswired installations 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, reactive power, apparent power, demand power, predicted demand power, power factor, accumulated energy, accumulated reactive energy, total harmonic distortion (THD) of each current and voltage, and K-factor of each current. B. The current and voltage signals shall be digitally sampled at a rate high enough to provide valid data for waveform analysis and true rms metering 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 amps for 1 second. D. All setup parameters required by the Circuit Monitors shall be stored in nonvolatile memory and retained in the event of a control power interruption. Any battery or other device used to provide non-volatile memory shall be serviceable from the front of the circuit monitor and servicing shall not require removing the circuit monitor from the gear in which it is mounted. E. The Circuit Monitor shall maintain in nonvolatile memory maximum and minimum values for each of the instantaneous values reported as well as the time and date that the minimum or maximum was set. F. The Circuit Monitors shall accept inputs from industry standard instrument transformers (120 VAC secondary PTs and 5 A secondary CTs). Connection to 480Y/277 VAC circuits shall be possible without use of PTs. In the interest of safety, provision shall be made that if PTs are not used, it shall not be necessary to bring voltages greater than 120 VAC (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% of full scale for voltage and current metering and 0.3% for all power and energy functions. 1. These accuracies shall be maintained for both light and full loads. 2. No annual recalibration by users shall be required to maintain these accuracies. 3. Voltage and current for all phases shall be sampled simultaneously to assure high accuracy in conditions of low power factor or large waveform distortions (harmonics). H. Any Circuit Monitor may be applied in three-phase, three- or four-wire systems. A fourth CT input shall be available to measure neutral or ground current. If the fourth CT is not used, then a residual current shall be calculated by vectorial addition of the phase currents. In four-wire connections the Circuit Monitor shall utilize the circuit neutral common reference and not earth ground, to provide metering accuracy. I. The Circuit Monitor shall be capable of being applied without modification at nominal frequencies of 50, 60, or 400 Hz. J. The Circuit Monitor shall operate properly over a wide range of control power including VAC or VDC. Connections to

47 Suggested System Specifications VDC shall also be available. Ride through capability should also be available for backup control power for up to 8 seconds. K. The Circuit Monitor shall surface or flush mount to an enclosure and be provided with an attractive finish bezel ring. 1. The Circuit Monitors shall be equipped with an integral, continuous duty, long-life display to provide local access to the following metered quantities as well as the minimum and maximum value of each 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 allowed from 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 the Circuit 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 protection against unauthorized/accidental changes. 18. For ease in operator viewing, the display shall remain on continuously, with no detrimental effect on the useful life of the Circuit Monitor. L. The Circuit Monitor shall be equipped with a front panel communications port as standard equipment. The port shall be completely accessible during normal operation and shall not require exposure of the operator to life-threatening voltage when in use. The operator shall be able to quickly connect a small Personal Computer (PC) to this port without use of tools or splices. This front panel port shall have all of the communication functionality of the standard hard wired rear port. When a connection is made to the front port, the Circuit Monitor shall disregard communication from the rear port until the front port is disconnected. M. It shall be possible to field upgrade the firmware in the Circuit Monitor 47

48 Suggested System Specifications to enhance functionality. These firmware upgrades shall be done through either the front or rear communication connection. No Circuit Monitor disassembly or changing of integrated circuit chips shall be required. It shall not be necessary to de-energize the circuit or the equipment to upgrade the firmware. N. The following metered values as well as the minimum and maximum instantaneous readings since last reset shall be communicated by the Circuit 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 following calculation 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 in five minute increments. Block interval, with optional sub-intervals. The window length shall 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 5-30 minutes in 5 minute intervals. External Pulse Synchronization, utilizing a synch pulse provided externally. An optional status input shall be used to sense the pulse. Sliding block interval with continuous sliding 15 second subintervals. 1. The following demand readings shall be reported by the Circuit Monitor: a. Average demand current, per phase b. Peak demand current, per phase c. Average demand for real power, reactive power, and apparent power d. Predicted demand for real power, reactive power, and apparent power e. Peak demand for real power, reactive power, and apparent power 48

49 Suggested System Specifications 2. The default demand calculation method shall be a 15 minute sliding window thermal demand. P. Each Circuit Monitor shall be capable of receiving a broadcast message over the communications network that can be used to synchronize demand calculations by several Circuit Monitors. This message need not be 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 for energy flow in each direction shall be kept, as well as an arithmetic sum. 2. Each Circuit Monitor shall be capable of operating a solid state KYZ output relay to provide output pulses for a user definable increment of reported energy. Minimum relay life shall be in excess of one billion operations. R. All Circuit Monitors shall include current and voltage waveform capture capability. 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 a Personal Computer Workstation (PCW) running the appropriate Power Monitoring and Control Systems software, or by the circuit monitor as a user defined response to an alarm condition. In addition, an external trigger can initiate the 12, 24, 36, 48, or 60 cycle waveform. The waveform capture sequence shall be initiated within 1 millisecond after the trigger is sensed. (A user definable delay shall determine how many of the cycles are shown before and after the trigger event.) 2. The Circuit Monitor shall capture, and store in internal memory, 64 digitally sampled data points for each cycle of each phase voltage and current. 3. The Circuit Monitor shall transmit the waveform samples over the network to the personal computer workstation for display, archival, and analysis. 4. Each voltage and current of all the phases shall be sampled concurrently so that proper phase relationships are maintained, so that harmonic flow analysis can be performed, and so that the effect of a disturbance can be observed on all phase voltages and currents. 5. Harmonic analysis performed on the captured waveforms shall resolve harmonics through the 31st. 6. The data used for the four cycle waveform capture display shall also be used to derive metered quantities in order to provide meaningful additional data. 7. All waveforms must reflect actual circuit performance. Waveforms synthesized or composed over time shall not be acceptable. S. Data logging may be accomplished either within the circuit monitor or at the PCW, or both. Each circuit monitor shall be able to log data, alarms and events, and multiple waveforms. The monitors shall offer up to 356 KB of on-board non-volatile memory. This information shall be communicated to the PCW upon demand. Logged information to be stored in each Circuit Monitor includes: 1. Up to 14 separate data logs shall be configurable by the user. Each log entry shall be date and time stamped. The type of data for the 49

50 Suggested System Specifications log shall be selected from a list of 175 monitored values. Each log entry shall be user configurable to consist of from one to over 75 values of instantaneous data, depending on the type of data. It shall be possible to set up each log to take data at a different user defined schedule interval. In addition, it shall be possible for a user to define an event or new min/max condition that will trigger log file entries. 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 the minimum and maximum of each of the instantaneous metered values. 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 from over 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 be scheduled at a user defined interval, externally triggered, or forced in response to a user defined event. Waveform logs shall be either Fill & Hold or Circular (FIFO) as defined by the user. 6. A simple user interface shall be available to enable the user to allocate Circuit Monitor memory to different log functions. T. Circuit Monitor Input/Output Options: Input/Output modules shall be field replaceable. Circuit Monitors shall be equipped with one of the following I/O options as shown on the project drawings: 1. Option One - One solid state output suitable for KYZ pulse initiation; one solid state input suitable for external end of demand interval demand pulse detection 2. Option Two - One solid state output suitable for KYZ pulse initiation; eight solid state status inputs 3. Option Three - One solid state output suitable for KYZ pulse initiation; four solid state status inputs; three mechanical output relays 4. Option Four - One solid state output suitable for KYZ pulse initiation; four solid state status inputs; three mechanical output relays; 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 pulse initiation; four solid state status inputs; three mechanical output relays; 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 pulse initiation; four solid state status inputs; three mechanical output relays; 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 pulse initiation; four solid state status inputs; three mechanical output relays; 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 50

51 Suggested System Specifications 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 to define a pick-up, drop-out, and delay. 3. There shall be four alarm severity levels in order make it easier for the 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 the communication link, or set to operate in response to user defined alarm event. 2. Output relays shall close in either a momentary or latched mode as defined by the user. 3. Each output relay used in a momentary contact mode shall have an independent timer that can be set by the user. 4. It shall be possible for individual relay outputs to be controlled by multiple alarms in a wired OR configuration. W. All Circuit Monitors noted on the project drawings shall include sag and swell detection capability. This capability is characterized by the following features: 1. The Circuit Monitor shall continuously monitor for disturbances in the 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 be used by the circuit monitor to determine if an event has occurred. The threshold shall be user defined as either a fixed setpoint or relative setpoint. When using the relative setpoint, the Circuit Monitor will set the nominal current or voltage equal to its present average value. The Circuit Monitor will automatically adjust the nominal current and voltage values to avoid nuisance alarms caused by gradual daily variations of currents and voltages. 4. Upon detecting a disturbance, the Circuit Monitor shall be capable 51

52 Suggested System Specifications of : a. Logging a waveform of the event, 12, 24, 36, 48, or 60 cycles in length, of all phase currents and voltages. The sample rate shall be of sufficient resolution to show the 31st harmonic for each cycle. b. Operating any output relay on an optional I/O module. c. Recording the disturbance into an event log with a date and time stamp to the millisecond. d. Causing an operator alarm at the PCW workstation. 5. All data and waveform logs shall be communicated over the local area network or through the front panel communications port so that the user may view and analyze the data using the PMCS software and workstation. X. Where indicated on the drawings, the Circuit Monitors shall be designed to run customized programs to greatly expand the Circuit Monitor s functionality for the particular installation. 1. These programs shall be written in a circuit monitor programming language similar to a compiled BASIC language. It shall include the 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 to the Circuit Monitor, such as changing computer chips or cards. All changes shall be done via either of the communications ports. 4. Examples of custom programs would include: a. Metering of specialized utility rate structures, including real time 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 power factor correction, based on multiple conditions e.g. time of day and input status Y. Advanced harmonic information shall be available via the Circuit Monitor. This shall include the calculation of the harmonic magnitudes and angles through the 31st harmonic. 1. This information shall be available for all three phases, current and voltage, plus the neutral current. (To ensure maximum accuracy for analysis, the current and voltage information for all phases shall be obtained simultaneously from the same cycle.) 2. The Circuit Monitor shall have a minimum of 100k of on board 52

53 Suggested System Specifications memory to log harmonic magnitudes and angles. 3. The harmonic magnitude shall be reported as a percentage of the fundamental or as a percentage of the rms values, as selected by the user MOLDED CASE CIRCUIT BREAKER ELECTRONIC TRIP UNITS A. Electronic Trip Units shall be provided as designated on the project drawings. All Electronic Trip Units shall be UL Listed. B. They shall provide the following breaker/trip unit information to the PMCS 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 ground ammeter information to the PMCS network. D. The Electronic Trip Units shall provide the following trip information to the 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 maintenance information 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 true rms sensing and provided as designated on the project drawings. B. The trip units shall be integral to the circuit breaker, and include the following: 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 I 2 t on short time and ground fault] 10. [Zone selective interlocking] C. The trip unit shall include an integral, four digit, alphanumeric display to indicate the following: 1. Amperes 2. Peak power (MW) 3. Present power (MW) 4. Energy (MWh) 53

54 Suggested System Specifications 5. Mode of trip 6. Service trip messages D. The trip units shall be powered from within the circuit breaker without the need for an external power source. Optionally, control power for display and communication may be provided by an external source as indicated on the project drawings. E. They shall have the ability to communicate up to 19.2 k baud on the PMCS network without the need for additional communication interfaces. F. The trip units shall provide the following breaker identification information to the PMCS network: 1. Frame size 2. Rating plug and multiplier G. The following trip information shall be available over the PMCS network: 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 the PMCS 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 pickup setting I. It shall be possible to operate the breaker remotely via the PMCS network. This function shall be password protected. J. The following metered values shall be available over the PMCS network: 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 threephase average 8. Present, peak, and predicted demand power (kw). K. The following values shall also have minimum and maximum readings available: 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 separate totals for energy flow in each direction, as well as an arithmetic sum. M. The power demand shall be calculated using the sliding window method 54

55 Suggested System Specifications with a user selected window of 5-60 minutes, in 5 minute intervals TRANSFORMER TEMPERATURE MONITORS A. Transformer Temperature Monitors shall be provided for each dry-type and cast resin transformer noted on the project drawings. All Transformer Temperature Monitors shall be UL Listed. B. The Transformer Temperature Monitors shall provide the following information 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 drawings shall be able to model (learn) the thermal loading of the motor and cool down characteristics to maximize protection during continuous and load cycling operation. B. Each unit shall be equipped with industry standard RS-485 data communications and utilize the same data communication cables as the other power monitoring devices in the system. C. Historical operating information such as running hours since last commissioning, number of starts/trips since last commissioning, number of overload trips/ground fault trips and similar data shall be displayed on the front of the device and be available via data communications to programmable logic controllers and personal computer workstations throughout the PMCS network for control, alarming, data logging, and event recording. D. The Motor Protective Devices shall provide fault diagnosis data such as pre-trip motor and ground fault currents, unbalance ratio, and maximum stator RTD temperature. E. Each motor circuit noted on the drawings shall be equipped with a Circuit 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 DIGITAL PROTECTIVE RELAYS A. Digital protective relays shall be installed as noted on the project drawings. These relays shall accept three-phase inputs from industry standard 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 from several different families. Families of curves shall include definite time, inverse, very inverse, extremely inverse and ultra inverse. All families of curves shall be suitable for coordination in typical medium voltage applications; the ultra inverse curves shall be provided to enhance coordination with fuses. D. A front panel keypad and display shall be provided. From this front panel it shall be possible to: 55

56 Suggested System Specifications 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 the communications 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 and demand currents per phase to the PMCS software. 4. Communicate breaker status, and type of trip including fault magnitude 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, preconfigured screens displaying data from the electronic trip units in an organized manner. The system display shall be UL Listed. B. System Display Installation 1. System Display units shall be installed by the manufacturer in the switchgear as indicated on the drawings. 2. The System Display units shall be flush mounted on switchgear door panels. C. System Display for Electronic Trip Units 1. System Display units shall be provided for display the data available from selected Electronic Trip Units connected on the individual data transfer network. 2. The System Display unit shall utilize a 4 line by 20 character, high contrast LCD technology display with back lighting to provide high reliability 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 to extend the life of the display. 5. Data shall be displayed in a logically organized manner complete with the proper scaling and units. D. System Display Keypad 1. The System Display unit shall allow for easy operation by providing a keypad with large keys for operator selections. 2. The keys shall have a raised perimeter and tactile feedback to provide a positive response even with gloved hand operation. 3. The keys shall be clearly marked to indicate the function and separated into meaningful groups with display prompting to assist the user in operation. 4. It shall be possible to sequentially view all available data from a selected device by single keystrokes advancing through the various 56

57 Suggested System Specifications display pages. 5. It shall be possible to view the same pages of data from other Electronic Trip Units by single keystroke advancing back and forth from device to device. E. System Display Configuration 1. Each System Display unit shall be configured by the manufacturer with all necessary data. 2. It shall be possible to change the configuration for each System Display unit using the keypad provided on each display. 3. Access to configuration functions shall be password protected to prevent 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, peak demands, and the time and date stamps stored in the Circuit Monitors. 3. These resets shall be limited to authorized persons by means of password protection PMCS NETWORK A. Connecting and Networking of Power Monitoring Devices 1. All data stored in the Power Monitoring Devices shall be accessible to external devices by means of RS-485 serial communications. 2. It shall be possible to connect from one communications port to another (daisy-chain) such that up to 32 Power Monitoring Devices may be connected to form a continuous communications link extending up to 10,000 feet. 3. Communications links shall be compatible with the RS-485 multidrop communications standards. 4. Communication rates on the links shall be adjustable up to 19.2 k baud to provide acceptable throughput of power monitoring device data. 5. It shall be possible to connect up to an unlimited number of communications links into a large network using ethernet hubs to form a high-speed power monitoring and control network. B. General Network Information 1. The PMCS shall be connected by means of Ethernet as the highspeed backbone network. 2. The high-speed network shall consist of POWERLOGIC Ethernet Gateways that allow display units, computers, programmable controllers, and other higher level or sub-networks to access the electrical data being gathered by the electronic Circuit Monitors, Electronic Trip Units, Transformer Temperature Monitors, Electronic Motor Protective Devices, and Digital Protective Relays. 3. It shall be possible to add an unlimited number of Personal Computer Workstations (PCWs) to the high speed network. Addition of a new PCW shall not require any modification to any existing PCWs. Adding PCWs shall require only a simple network tap; extensive rewiring or wiring to each group of monitoring devices shall not be required. 4. Each personal computer connected to the network shall be a Windows NT or Windows 95 workstation with a standard Ethernet 57

58 Suggested System Specifications Network Interface Card (NIC). C. POWERLOGIC Ethernet Gateways 1. All of the power monitoring devices shall be connected to the Ethernet backbone by one or more POWERLOGIC Ethernet Gateways (EGW) as shown on project drawings. 2. The EGW shall connect to the Ethernet backbone via unshielded twisted pair cable (UTP) or fiber optics via an attachment unit interface (AUI) port. 3. The AUI port shall be equipped with control power (12V) such that an external power supply is not required to power the transceiver. 4. There shall be indicating LED s for the Ethernet connections to assist in trouble-shooting. Indicators are required for Transmit, Receive, Collision, Link and Polarity of the connection. 5. The Ethernet Gateway shall support Circuit Monitors, Power Meters, and other POWERLOGIC-compatible devices through one or more 4-wire, RS-485 communication ports via standard daisychain connections using Belden 8723 or equivalent. Each RS-485 serial port shall operate up to 19.2 kbaud. Each RS-485 serial port shall have a corresponding LED to indicate communications activity on the daisy-chain. 6. The EGW shall be fully TCP/IP compliant thereby allowing the power monitoring software access to power monitoring information from anywhere on the local area network (LAN) or via the Wide Area Network (WAN). 7. The protocol used over ethernet by the EGW shall be Manufacturers Messaging Specification (MMS) an international standard (IEC 9506) which is an open, well-defined protocol. 8. Setup of the EGW shall be accomplished via an integral, RS-232 interface on-board the EGW. All setup parameters shall password protected to guard against intentional and/or inadvertent access. It shall also be possible via this RS-232 port to upgrade the firmware of the EGW in the field to accommodate new system features. 9. All Ethernet cabling shall be installed by a qualified data communications cable installer or the electrical contractor qualified to install data communications equipment. All communications cabling shall be Category 5 rated for 100MB. 10. The system shall provide for secure operation via an encryption algorithm such that unauthorized personnel cannot intentionally or inadvertently alter the communication or setup parameters. 11. A dedicated Ethernet gateway shall be used which requires no hardware adjustments or modifications. Standard personal computers (PCs) or programmable logic controllers (PLCs) are not acceptable as gateways to the power monitoring and control devices 12. The Ethernet gateway shall be equipped with an integral power supply suitable for connection to 120VAC, 240VAC, 50/60Hz, or 125VDC input supply. The power supply input shall be fused and readily serviceable in the field. An external power supply is not acceptable. 13. The EGW shall be small, self-contained, and suitable for mounting in an electrical closet, telephone room or network room. It shall also be suitable for mounting in instrument compartments in electrical equipment. It shall be no larger than 5"H x 8"W x 10"D in size. It shall be possible to side or top mount the EGW using optional mounting brackets. 58

59 Suggested System Specifications D. Interface to Existing Systems 1. The high-speed network utilized by the PMCS system shall permit easy interface with the Building Automation System (BAS). a. Data located in the power monitoring devices and PLC registers and associated inputs/outputs shall be made available to the BAS vendor via Circuit Monitor and/or programmable controller register lists. b. Hardware and software required by the BAS to retrieve this data from the PMCS data highway shall be the responsibility of the BAS vendor. 2. The network shall have POWERLOGIC Ethernet Gateways installed as noted on the project drawings that allow electrical plant information flow with existing POWERLOGIC networks. a. Data located in the power monitoring devices and PLC registers and associated inputs/outputs shall be made available to the factory automation vendor via Circuit Monitor and/or programmable controller register lists. b. Hardware and software required by the factory automation system to retrieve this data from the PMCS data highway, shall be 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 the PMCS vendor as required. Use of fiber optics shall be transparent to PMCS software and monitoring devices. 2. Telephone modems shall be installed where shown on the project drawings. Telephone modems and interface hardware shall be provided by the PMCS vendor as required. Use of telephone modems shall be transparent to PMCS software and monitoring devices. 3. Wireless ethernet shall be installed where shown on the project drawings. Wireless ethernet and interface hardware shall be provided by the PMCS vendor as required. Use of wireless ethernet shall 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 PMCS vendor and installed as necessary. Ethernet network connections shall be established using industry standard Ethernet protocols such TCP/IP. All components shall work with existing Ethernet Gateway, Router, and Hub technology. Use of Ethernet shall be transparent to PMCS software and monitoring devices PERSONAL COMPUTER WORKSTATIONS (PCWs) A. The PMCS shall include Personal Computer Workstations complete with PMCS Application Software as specified as in Article 2.11 of this specification, and shall be located as designated on the project drawings. It shall be pre-configured with all software, configuration files, and oneline drawings by the vendor and ready to connect and operate when delivered to the job site. B. Hardware Requirements 1. The PMCS system shall also include [ ] factory supplied Personal Computer Workstations capable of displaying information from all Circuit monitors. 2. Each Workstation shall consist of a Pentium or higher CPU, color 59

60 Suggested System Specifications VGA monitor, Microsoft Windows NT/Windows 95, network interface 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 hard disk space minimum). 3. It shall be possible to operate networked computer workstations in a client/server environment to allow data sharing and viewing with/on any computer on the network. Each workstation shall have complete access to all PMCS information. The number of workstations connected on the network shall not be restricted. It shall also be possible to have one or more standalone computer workstations in a monitoring system where PC networking is not required. C. Software Requirements 1. The manufacturer shall supply PMCS application software which provides the operator user friendly access to all Circuit monitor data, breaker/contactor/switch status and manual control, communication alarms, captured waveforms and logged data. 2. In addition to the PMCS application software programs, each PCW shall permit the use of other software programs as desired by the user PMCS APPLICATION SOFTWARE A. General 1. The PMCS shall be supplied with user-friendly application software suitable for operation on personal computer workstations which serve as central control stations by monitoring the devices in the system, recording events, indicating alarm conditions, and displaying and logging device data. 2. The software shall be developed by the manufacturer of the monitoring devices, and shall be designed specifically for power monitoring. 3. The vendor shall provide a list of all the software needed on the project and indicate which packages are being supplied. 4. The vendor shall describe the procedure to be used to allow the software to support additional monitoring devices at a future date, including graphics. The description shall be in sufficient detail to allow the user to make the modifications without vendor support. 5. The software shall be configured, not programmed. All software shall be configured by the vendor and delivered ready to use. This configuration shall include preparation of all graphics, displays, and interactive one line diagrams required as a part of this project. 6. Any development keys or programming tools needed by the user to make modifications to the screens, interactive one-line diagrams, or displays shall be provided by the vendor. 7. The vendor shall pre-configure the software to be ready to display data from at least 20 additional monitoring devices that may be added at a later date. Configuration shall be to the point that when additional monitoring devices are added, the user shall only need to convey to the software the communications address and type of the new device. The software shall then be able to display all data from that device in a format identical to that used for other devices of the same type. 8. The software vendor shall offer regularly scheduled classes to provide instruction on using application software and associated monitoring devices to manage a PMCS. 60

61 Suggested System Specifications B. Software Options Application Software shall be supplied by the PMCS manufacturer to support system configuration, monitoring of the devices, data logging, alarming, and other operations associated with the PMCS. Each Personal Computer Workstation (PCW) shall be equipped with PMCS software from the options listed below, as noted on the project drawings. Different PCWs can have different software options installed; installation of a given software option on any PCW shall not limit the software options on any other PCW. The software package(s) noted on the project drawings and described below, fully configured by the vendor, shall be provided. 1. Windows NT/Windows 95 Platform a. Microsoft Windows NT/Windows 95, 32 bit client/server application provides both standalone monitoring and network connectivity solutions over the PC LAN or WAN. Network capabilities allow remote access and data sharing of real-time power system information. Applications are designed to monitor the entire system of power monitoring devices in the background for alarms, events, and data logging, allowing the operator to perform other tasks with the workstation. b. The following core products shall be provided as noted on the project drawings. In addition, all add-on modules described below shall be provided as noted in the project drawings. 1) Basic Power Monitoring - Standalone (PMX-1500). This software package shall operate on either Windows 95 or Windows NT. It shall be used where all of the power monitoring data shall be retrieved and displayed on individual PCs. (a) Shall support over 1000 PMCS devices, and poll all as required. (b) Shall provide security to protect system data. (1) Shall support unlimited user accounts, each with a unique name and password. (2) Shall provide ten privilege access levels that determine which functions each user can access. (3) Set up functions shall be password protected. (c) Device setup shall be accessible in both on-line and off-line modes. (d) Shall permit device setup including configuration of circuit monitor data and waveform logs. Shall allow the user to define circuit monitor alarms and configure circuit monitor relay operation. (e) Shall allow devices and quantities to be organized into logical groups (function, location, department, etc.). Groups shall be user defined, each group having a unique name. (f) Shall provide resets of all supported devices. Shall allow resets by device or by group of devices. (g) Shall include an on-line, context sensitive help system. (h) Events shall be recorded in an Event Log. (1) Event Log shall be capable of holding at least 1000 events. The actual number of events shall 61

62 Suggested System Specifications user defined and only be limited by size of storage drive. (2) The Event Log shall record date/time of the event, event description, and user name (if applicable). (3) The Event Log shall record occurrences that are related to the operation of the software such as breakers opening, or closing, loss of power, loss of device communications, user logon, changes to system setup, etc. (i) Shall monitor for alarm conditions detected by each device and indicate the alarm at the PCW. (1) Alarms shall be user defined pick-ups and dropouts. (2) Shall include pre-defined system alarms. (3) Ten severity levels for analog and digital alarm conditions shall be supported. (4) Each severity level shall provide user selected indication including audible, visible, and/or required acknowledgment. (5) Alarm severity levels shall allow further customization by requiring password acknowledgment of alarms and by associating a unique color and/or sound with the level. (6) Alarms shall be reported by exception. (7) At any time, a summary of all active alarms may 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 displays of electric plant information. (l) Shall log PMCS data to the PC hard disk at user specified intervals. (1) Shall be capable of exporting logged data to other file types used by other common commercially available software products. (2) Shall allow logging of non-electrical quantities such as water, gas, steam, and air pressure. (m) Shall retrieve and display tables of historical data recorded over time. (n) Shall provide time trend plots of historical data over time. (1) Shall be possible to overlay on the same plot information from multiple circuit monitors. (2) Shall be possible to plot only a portion of the total data available. (3) The user shall be able to specify the beginning and ending date and time of the data to be plotted. (o) Shall retrieve and display data and alarm and event logs created and stored in circuit monitors. 62

63 Suggested System Specifications (p) Shall capture and log waveforms and harmonic information based on user specified criteria. (1) Shall provide graphical waveform displays for the voltages, phase currents, and residual current monitored by circuit monitors. (2) The following information shall be calculated and displayed based on minimum of 4 cycles of data: (a) Total Harmonic Distortion (THD), rms magnitudes, peak values, Crest Factors (CF), and magnitudes of the individual harmonics. (b) All harmonics calculations shall be based on samples covering multiple cycles in order to reduce inaccuracies caused by sampling discontinuities. (3) Shall retrieve, display, and store 4, 12, 24, 36, 48, and 60 cycle waveforms from circuit monitors. (q) Shall allow Dynamic Data Exchange (DDE). (1) Shall serve system data to other applications supporting DDE for advanced reporting and graphics. (2) Shall read, display, log, trend, and alarm DDE data from other applications. (3) Shall allow the creation of custom quantities to read DDE quantities from other applications and metered values from other utilities (gas, water, steam, and air pressure). (r) Shall enable monitoring in more than one location by dialing up remote sites and automatically polling devices. (s) Shall comply with the Open Database Connectivity (ODBC) standards of data storage to allow other software products easy access to the stored information. Shall be possible to format data stored by the server for any ODBC database. (t) After power loss and restoration shall restart automatically, go on-line and resume logging and alarming. (u) Shall be capable of password-protected control of system operations from the PCW including the operation of Circuit monitor outputs, PLC outputs, electronic trip units, digital protective relays, and other devices. (v) Shall allow user to create custom tables for viewing electric system information in convenient formats. Custom tables shall be easily modified as need arises. 2) Full System Power Monitoring - Standalone (SMS-1500) (a) Shall have all functionality of Basic Power Monitoring - Standalone (PMX-1500) described above and the additional functionality described below. (b) Shall include a task manager scheduling capability 63

64 Suggested System Specifications that provides automated program operations for repetitive tasks. Such tasks shall include scheduled resets, device log and file retrieval, generating and printing reports, launching executables, sending , and activating beepers. Frequency and execution of automated tasks shall be user defined. (c) Shall provide real time, user friendly bar chart and meter displays of electric plant information. (d) Shall allow creation of custom real time trend plots, charts, and meter panels for viewing electric system information in convenient formats. Custom displays shall be easily modified as the need arises. (e) Shall allow user to develop reports for any displayable electrical system information. (1) Shall provide options to simplify routine printouts of various data for standard reports. (2) User shall be allowed to modify reports. (f) Shall allow the user to save and retrieve computer workspaces 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 Power Monitoring Standalone (SMS-1500) described above, with the following exception: the software shall communicate with one device at a time. 4) Advanced System Power Monitoring - Client/Server (SMS-3000) (a) Shall have all functionality of Full System Power Monitoring - Standalone (SMS-1500) described above, and shall provide these functions on the same PC and/or distribute information processing across the PC LAN or WAN. The server shall operate on Windows NT, while the client s may operate on Windows 95 or Windows NT. (b) Shall display system information on the local PC and on any client PC that is accessible via the PC LAN or WAN and has the appropriate PMCS software (see Section c. below, Optional PMCS software add-on modules.) (1) Shall allow connection to network server via modem to access system information and acknowledge alarms from a PC or laptop at any remote location. (2) Shall broadcast alarms across the PC LAN or WAN. (3) Shall log PMCS data to any logical drive including the local computer hard disk and any remote drive accessible via a network PC or server. c. Optional PMCS client software for use with the Windows NT and Windows 95 based, system monitoring applications described above include: 1) Power Monitoring Client (PMX-1000) - [requires SMS- 64

65 Suggested System Specifications 3000] (a) Shall be located wherever needed on any PC in the monitoring system connected to the server via LAN, WAN, or modem. (b) Shall display all system information listed above in Basic Power Monitoring - Standalone (PMX-1500) collected by the network server from the power monitoring devices. 2) System Manager Client (SMS-1000) - [requires SMS- 3000] (a) Shall be located wherever needed on any PC in the monitoring system connected to the server via LAN, WAN, or modem. (b) Shall display all system information listed above in Advanced System Power Monitoring Client/Server collected by the network server from the power monitoring devices. 3) Interactive Graphics Client (GFX-1000) - [requires PMX- 1500, SMS-121,SMS-1500, or SMS-3000]. The Interactive Graphics Client shall reside independently on separate PCs networked to the server, or on any PC with any other PMCS power monitoring software as indicated on the drawings. (a) Interactive Graphics software shall be provided that is compatible with the PMCS software. (b) Shall be located wherever needed on any PC in the monitoring system connected to the server via LAN, WAN, or modem. (c) The software shall display real-time information collected by the network server from the power monitoring devices on custom drawings including power one-line system drawings, equipment elevation drawings, shop floor layouts, legends, process drawings, etc. (d) It shall be possible to display any of the quantities available from the power monitoring devices or programmable logic controllers in the location, size, and color selected by the user. (e) The software shall provide the ability to perform executables and launch other programs. (f) The Interactive Graphics software shall allow the user to zoom, scale, and scroll the drawings to the desired degree of magnification. (g) The software shall be capable of displaying status of circuit breakers (open/closed/tripped), status of transformer fans (on/off), transformer coil and motor temperatures, power factor capacitors (on/off), POWERLINK AS circuit breaker status and control, and other information available on the PMCS network. The data shall be available in multiple formats value blocks, meters, and bar charts. (h) From within any drawing the user shall have the ability to link and display drawings in a hierarchical fashion to allow quick access to related drawings. 65

66 Suggested System Specifications (i) The Interactive Graphics software shall allow the user to manually control various system operations with proper password entry (e.g. load transfer). (j) Analog functions blocks shall be included to display the condition (e. g. high, low, or alarm) of any metered quantity such as current, voltage, temperature, etc. (k) Components shown on one-line diagrams shall be color-coded based on the on/off status signals form the device. (l) Vendor shall supply custom graphic screens based on user supplied drawings. 2. Software Service Agreement a. The electrical equipment manufacturer shall include a [ ] [1], [2], or [3] years Software Service Agreement which provides customer with software upgrades for the software specified above as they are available AUTOMATIC CONTROL A. Programmable Logic Controllers (PLCs) shall be provided which communicate with the Circuit Monitors Electronic Trip Units, Transformer Temperature Monitors, Motor Protective Devices, Digital Protective Relays, and other compatible devices for performing control operations. B. Each PLC shall include ladder programs which will direct the automatic control operations as specified. C. Processor, input, output, and network interface cards shall be provided as necessary to implement the sensing and automatic control operations. D. Data pertaining to the automatic control system shall be transmitted via the PMCS network to the remote personal computer workstations. 1. PLCs and PCWs shall operate independently of each other, and shall not be affected by the operation of any other PCW. E. At a minimum the application software at the personal computer workstation 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, relay operation, etc.) shall be date/time stamped and recorded in an event log. 3. Setup and display alarm conditions for automatic control operations shall be possible with each alarm condition entered in the event log. 4. Manual operator intervention via the keyboard or interactive oneline graphics shall be provided such that any point in the process may be controlled. 5. Manual intervention shall be password protected to prevent inadvertent or unauthorized override of the control scheme. 6. Protective relaying functions, anti-paralleling interlocks, or load limits shall not be defeatable. PART 3 EXECUTION 3.01 INSTALLATION A. PMCS components, including Circuit Monitors, Electronic Trip Units, 66

67 Suggested System Specifications Transformer Temperature Monitors, Motor Protection Devices, and Digital Relays, included within the power equipment lineups shall be factory installed, wired and tested prior to shipment to the job site. B. All control power, CT, PT and data communications wire shall be factory wired and harnessed within the equipment enclosure. C. Where external circuit connections are required, terminal blocks shall be provided and the manufacturer s drawings must clearly identify the interconnection requirements including wire type to be used. D. All wiring required to externally connect equipment lineups shall be installed by the electrical contractor. E. Contractor interconnection wiring requirements shall be clearly identified on the PMCS system drawings. END OF SECTION 67

68 Glossary of Terms access Allowed availability to information on a network. accumulated energy A running accumulation over time of the energy monitored in a given circuit. The total energy consumed is obtained by continuously integrating instantaneous real power with respect to time. accumulated reactive energy A running accumulation over time of the reactive energy 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 varies in a continuous manner. asum The arithmetic sum of the magnitudes of the fundamental and individual harmonics 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 current calculated using a sliding window over a given time interval. Also known as thermal demand current. average demand current, Phase B Average demand for Phase B current calculated using a sliding window over a given time interval. Also known as thermal demand current. average demand current, Phase C Average demand for Phase C current calculated using a sliding window over a given time interval. Also known as thermal demand current. average demand real power Average demand for real power calculated using a sliding window over a given time interval (ranging from 1-60 minutes in 1 minute increments for the circuit monitor). Baud rate The rate of speed at which information is transmitted over communication lines, expressed in bits per second. bit A contraction of binary digit, the smallest unit of information in binary notation. A bit is a zero (0) or a one (1), i.e., the binary of number of 0110 consists of four bits. bit rate The rate at which binary digits, or pulses representing them, pass a gioven point 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 and control device capable of replacing a variety of meters, relays, transducers and other components. circuit monitor label A user-definable, alphanumeric field associated with the circuit monitor. circuit monitor nameplate data A user-definable, sixteen character field used to identify a circuit monitor and its use. For example, if the circuit monitor supplied power 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 inner conductor, separated from each other by insulating material. communications link Equipment, especially transmission cables and interfaces, which complete the communications connections and permit the transmission of digital signal data. communications microprocessor The circuit monitor microprocessor which is responsible for communication to/from the host, receiving data from metering microprocessor, accurately maintaining clock and calendar, keeping the min/max of calculated values, and control of digital inputs/outputs. continuous rating Maximum constant load that a device can carry continuously without exceeding its temperature rise specification. crest factor (CF) Ratio of peak to rms values of voltage or current. Crest factor is equal to for a purely sinusoidal signal. 68

69 Glossary of Terms CT rating A user-definable parameter which represents the primary rating of the current transformers connected to the circuit monitor. current, percent apparent distortion The difference in percent between the true rms current and the rms value of a pure sinusoid with the same peak current as the 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 flowing in the 3 phases. current transformer An instrument transformer intended to have its primary winding connected in series with the conductor carrying the current to be measured or controlled. cycle Unit of frequency of alternating current, equal to 1/60 second or milliseconds. daisy chain The physical method of cabling devices in series. demand interval The time interval used in the average demand calculations for real power. device address door The sliding door located on the rear of the circuit monitor which covers the devices address switches. device address switches Two ten position rotary switches, accessed from the rear of the circuit monitor, which are used to set the address of the circuit monitor 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 data transmission in both directions. Half-duplex allows data transmission in either of two directions, but only one direction at a time. energy management alarms A user-definable parameter which indicates when the 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 coaxial cable as a passive communications medium to interconnect differnet kinds of computers, information processing products, and offie equipment at a local site. fiber optics A medium that uses light conducted through glass or plastic fibers for data transmission. flag A signal device in a microprocessor system that alerts the operator, or the system 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 communications channel. fundamental Term for value of voltage or current corresponding to the portion of the signal at the power frequency. Usually the power frequency is 60 Hz, but may be 50 Hz (Europe) or 400 Hz (aviation). gateway In local area networks (LANs), a computer system and its associated software that permit two networks using differerent protocols to communciate with each other. A gateway translates all protocol levels from physical layer up through applications layer, and can thus be used to interconnect networks that differ 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 conducting body serving in place of earth. half-duplex Two-way, but not simultaneous, transmission of data through a communications channel. interface A device that allows communication between systems or ports of systems. 69

70 Glossary of Terms K-factor Relates the heating effect of a distorted current in a transformer to a sinusoidal 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 of entering data into memory. master-slave A mode of operation where one data station (the master) controls the network access of one or more data stations (the slaves). metering microprocessor The circuit monitor microprocessor which does the real time monitoring of the current and voltage inputs. It reads the A/D converters and makes the required calculations on the raw data. millisecond (ms) One thousandth of a second: 1 x 10-6 or second. multipoint communications Method of communication in which a single device can 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 National Electrical Manufacturers Association. network A group of computing devices that are connected to each other by communication lines to share information and resources. non-volatile memory Memory which retains its contents upon loss of power. The circuit monitor stores many values in non-volatile memory. OHM s Law Current (I) in terms of electromotive force (E) and resistance (R) given by the equation I = E/R. on-line Describes equipment or devices which are involved in direct communications. operating system (OS) Integrated programs that work together to manage and improve the operating effectiveness of a computer or system. OSI Abbreviation for Open Systems Interconnection. Network model developed by the 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 of the waveform. peak demand current Phase-A The maximum value recorded for average demand current for Phase A since last reset. peak demand current Phase-B The maximum value recorded for average demand current for Phase B since last reset. peak demand current Phase-C The maximum value recorded for average demand current for Phase C since last reset. peak demand real power The maximum value recorded for average demand real power since last reset. peripheral Those devices which support but are not directly involved in the operation. point-to-point communications Method of communication in which a device communicates to only one other device at a time. polling A method by which all equipment sharing a communications line can be periodically interrograted or allowed to transmit without contending for the line; often a reference to a centrally controlled method of accessing a number of devices. potential transformer An instrument transformer that is intended to have it primary winding connected in shunt with a power supply circuit, the voltage of which 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 calculated as the 3 phase total real power divided by the 3 phase total apparent power. 70

71 Glossary of Terms power factor, Phase-A The cosine of the angular difference between the vetor s phase A current and phase A-N voltage. power factor, Phase-B The cosine of the angular difference between the vetor s phase A current and phase B-N voltage. power factor, Phase-C The cosine of the angular difference between the vetor s phase A current and phasec-n voltage. programmable controller A solid-state control system which has a user programmable memory for storage instructions to implement specific functions such as: I/O control logic, timing, counting, arithmetic, and data manipulation. protocol A standardized procedure for establishing a communications link between two devices based on such elements as word structure or length. PT rating A user-definable parameter which represents the primary rating of the potential transformers connected to the circuit monitor (assumes 120V secondary PTs). reactive power, 3-phase total The sum of the reactive power values for each of the 3 phases. read To copy, usually from one form of storage to another, particularly from external to secondary storage to internal storage. real power, 3-phase total The sum of the real power values for each of the 3 phases. real time Pertaining to the performance of a computation during the actual time that a related physical process transpires, in order that results of the computation 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 harmonic portion of voltage or current. This quantity provides information about the actual level (in volts or amps) of voltage or current harmonics. router A device that connects multiple networks together, providing path selection and alternate routing based on network destination addresses and the status of the connected networks. routing A technique which allows information to be sent from one device along a specified path (or route) to another device. The path is mapped by a statement offering the address of each device along the route. RS-422 interface An electrical interface which offers a standard of communication for electronic devices. The circuit monitor s RS-485 interface is RS-422 compatible. RS-485 interface An electrical interface which offers a standard of communication for electronic devices and offers multipoint communications. The circuit monitor utilizes 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 having the capabilities of all the separate units. system connection A user-definable variable which indicates whether a specific system is a 3-wire or 4-wire system. terminator A hardware load employed on the end of a transmission line or cable used to balance the impedance. THD (Total Harmonic Distortion) Indicates the degree to which a voltge or current signal is distorted. ThickWire (10BASE5) Standard Ethernet baseband coaxial cable that serves as the backbone transmission medium for the local area network. Primarily used for facility-wide installations. ThinWire (10BASE2) A wiring scheme which uses a type of (thin) coaxial cable for use 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 71

72 Glossary of Terms through an electrical panel. root-mean-square (RMS) The square root of the mean value of the square of the parameter values during a complete cycle. unidirectional maibox A technique used by the circuit monitor s microprocessors to exchange information in which each microprocessor has a separate mail box to 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 the communications 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 from a given phase s current and voltage waveforms. write To enter data into a storage device. 72

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74 Square D,,POWERLOGIC, POWERLINK, MICROLOGIC, LIFE-GARD, VISI/VAC, POWER-ZONE, SY/NET, and SY/LINK are registered trademarks of Square D Company. System Manager and EXPlorer are trademarks of Square D Company. All other product names listed in this document are trademarks of their respective companies. Bulletin No. 3000CT9701 December, Square D All Rights Reserved