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ELECTRICAL POWER MONITORING AND CONTROL GE Consumer and Industrial SECTION 16215 Electrical Power Monitoring and Control SPECIFIER NOTE This is Parts 1, 2 & 3 of Extended Section 16215 Electrical Power Monitoring and Control System. Specification is based on a GE PMCS system. The description contained herein is relatively complete and includes a GE EPM 9650 Power Quality meter. Other meters may be provided by GE and it is suggested the writer become familiar with the multiple products available as different metering capabilities may be desirable at different points in the Electrical System. PART 1 GENERAL A. The requirements of the Contract, Division 1, and Division 16 apply to work related to Protection Metering & Control System in this Section. 1.01 PRODUCT OVERVIEW / SUMMARY A. The Power Management and Control System offering shall provide reliable, upto-date information on the status of important processes and systems to the system operators. The system shall also provide a valuable backup for monitoring and control of the system status for diagnostic and forensic purposes. The Power Management and Control System (PMCS) offering must have open system architecture. The PMCS shall be a Windows XP or Windows 2003 Server based master control system software. This includes functions useful to the operation and maintenance of major electrical systems in the facilities, including, UPS systems, batteries, generators, ATS, paralleling switchgear, distribution boards, PDU systems, video cameras, fire systems, security systems, and off site or remote monitoring. B. The PMCS system includes UPS and apparatus predictive maintenance, motor/turbine predictive maintenance, energy analysis and cost allocation software modules. C. The system Human Machine Interface (HMI) shall be designed for the following functions: 1. Provide immediate analysis when a power quality event occurs. Used to correct equipment failures in-house or correlate an internal failure with a utility event. 2. Provide monitoring data to benchmark power quality levels at each facility and/or for the total organization. 3. Provide a single database for storing all disturbance monitoring and recording data that is needed for power quality, reliability, and fault analysis. 4. Provide power quality data to evaluate performance of power conditioning equipment. Show compliance with specification to include transfer times, voltage regulation, and harmonic output. 5. Requesting and receiving information from distributed facility Intelligent Electronic Devices (IEDs) using Modbus RTU IED protocols. 6. Gathering and locally storing historical operation/fault, events with original IED time stamping preserved. Options can be configured to logically ELECTRICAL POWER MONITORING AND CONTROL 16215 - 1 ELECTRICAL POWER MONITORING AND CONTROL GE Consumer and Industrial combine events, to eliminate duplicate events, or to display the events grouped by either time/day/month/year or by device. 7. Gathering and locally storing facility fault records and waveforms generated during the abnormal operation of facility devices. 8. Interfacing with enterprise level Wide Area Network (WAN). 9. Providing access to individual IEDs from either the facility or dial-in remote locations, using specific IED protocols. Dial-in should be telephone or via Internet. 10. Provide an information service that can be offered to customers for evaluation of the system performance and the impact of power quality variations on their equipment. 11. Provide continuous performance information to Account Managers for evaluation of customer power quality concerns. 12. Identify internal power quality problems before catastrophic failure. An example is predicting the failure of a UPS based upon its output harmonics and unbalance. 13. Provide a platform to support the automated monitoring and maintenance of the facility 14. Provide reports of power quality performance that can be used to prioritize system maintenance and capital expenditure plans. 15. Perform automated power quality audits and produce reports using Artificial Intelligence to pinpointing fault causes and possible preventive measures. 16. Produce summary graphs of CBEMA charts and time plots from the collected data. 17. The HMI shall have at least 30 standard building protocols available. 1.02 SECTION INCLUDES A. The Section includes Power Management Control Systems (PMCS) and the communication network of electrical power circuits as per Contract Documents B. Power Management Control System (PMCS) C. Communications network D. Metering and Protection Devices also called Intelligent Electronic Devices (IEDs) 1.03 REFERENCES A. The product description and protection devices in this specification are designed and manufactured according to latest revision of the following standards (unless otherwise noted). 1. NEC Article 725 Class II for Power Limited Circuits 2. EIA-485 for RS485 Modbus RTU (Remote Terminal Unit) 3. IEEE 802.3 for Ethernet 1.04 DEFINITIONS A. Modbus RTU: An industry standard, high-performance network communications protocol developed by Modicon. B. Open Protocol: An industry standard protocol that is published and used by many other manufacturers and is, therefore, non-proprietary. ELECTRICAL POWER MONITORING AND CONTROL 16215 - 1 ELECTRICAL POWER MONITORING AND CONTROL GE Consumer and Industrial C. RS 485 / EIA 485: A physical wiring standard for high speed, noise tolerant network communication often used with the Modbus RTU protocol. D. Ethernet: A high performance local area network standard providing the two lower levels of the ISO/OSI seven-layer reference model, the physical layer and the data link layer. Use Cat5e cabling for 100MB and Cat6 for 1 GB communications E. Ethernet Gateway: A physical device that translates communications protocol to Ethernet communications protocol. F. Communications Protocol: A formal set of conventions governing the control of Inputs and Outputs within the communicating process. G. Client/Server architecture: A network architecture in which each computer on the network is either a Client or a Server. Servers are computers dedicated to acquiring, archiving, and serving data. Clients, also called Viewers, are computers that present data from one or more Servers to the end user. H. OPC – OLE for Process Control. OPC is an open connectivity in industrial automation and the enterprise systems that support industry. Interoperability is assured through the creation and maintenance of open standards specifications. I. SCADA: System Control and Data Acquisition J. LAN: Local Area Network K. Modbus Concentrator: A physical device that converts data from CommNet devices to Modbus RTU protocol L. System Redundancy: Capability of a system to log and serve data to primary and secondary computer simultaneously and automatically switching over from the primary to the secondary computer in case of a failure, without losing any data. 1.05 SYSTEM DESCRIPTION A. Provide all components, software, and systems integration for a complete operational PMCS as specified. 1. The following devices shall communicate power system values and data via Modbus RTU connectivity, dry contacts, analog 4-20 ma signals, or a combination of each to the PMCS system. (Note: See product sections for specifications of these devices. See drawings for quantities and locations): a. Automatic Transfer Switches (ATS) b. Automatic Static Transfer Switches (ASTS) c. Batteries d. Generators e. Generator Paralleling Switchgear f. Distribution Boards g. Load Bank h. Main Switchboards i. Panel Boards j. Power Distribution Units k. Primary Service Switchboards l. Uninterruptible Power Supplies (UPS) m. Trip Units n. Meters/Relays o. Chillers ELECTRICAL POWER MONITORING AND CONTROL 16215 - 1 ELECTRICAL POWER MONITORING AND CONTROL GE Consumer and Industrial p. ODP Panels q. Computer Room Air Conditioning (CRAC) Systems r. Video Channels s. Fire Alarm t. Building Management Systems B. Provide options for a development software package (such that the owner is licensed to modify the software in the event of future expansion or equipment modifications) and a runtime only package. C. The system shall be equipped with a standard Human Machine Interface (HMI) / Supervisory Control and Data Acquisition (SCADA) software for displaying data from the power monitoring devices. The following customized graphic screens shall be provided: 1. Site plan 2. Animated one-line diagrams for each switchgear lineup including breaker status 3. Tabular data for monitored devices 4. Waveform Capture for supported devices 5. Alarms 6. Trends with four points per monitored device 7. Event log 8. Generator Control Panel (GCP) overview screen - One per GCP. 9. PLC tabular screen 10. UPS tabular data screen 11. PDU tabular data screen 12. Battery Monitor status screen 13. Device communication overview screen 14. Total harmonic distortion (THD) analysis screen D. The system shall also support the following functions: 1. Cost allocation of monitored devices over the web 2. Customer defined reports 3. Remote dial in capability for remote diagnostics and troubleshooting using a modem or Internet, and appropriate communications software. 4. Automatic power analysis and report generation for power quality events. E. WEB access and viewing F. Built in System Health Monitor to continuously monitor the functionality of the server and the software associated with the PMCS. G. The communications network shall consist of a combination of RS-485 Modbus RTU and Ethernet TCP/IP technology as indicated on the contract drawings. If another protocol is required, the vendor shall indicate the proprietary protocol and provide the equipment with gateway devices and/or drivers necessary to convert to Modbus RTU. Under no circumstances shall a proprietary protocol be accepted. H. Where LAN based communications are not available, the equipment vendor will make the appropriate data available via dry contact discrete signals and 4-20 ma ELECTRICAL POWER MONITORING AND CONTROL 16215 - 1 ELECTRICAL POWER MONITORING AND CONTROL GE Consumer and Industrial analog signals. The PMCS supplier will provide the necessary Input/Output devices to integrate those signals into the PMCS. I. The system configuration shall be capable of offering redundant computer operation. J. The system shall be IRIG-B time synchronization capable. K. The PMCS shall be a true Client/Server architecture. The system shall be capable of viewing (monitoring) critical system parameters from a workstation other than the server PC. The system shall support two types of remote viewing. The first type shall be with an individual viewer software license located on a client PC. The second type shall be with a server based web viewer software license and a commercially available web browser on the client PC. 1.06 SUBMITTALS A. Manufacturer shall provide copies of the following documents to the owner for review and evaluation in accordance with general requirements of Division 1 and Division 16: B. Functional description of the PMCS including proposed network configuration. C. Site test plan for the PMCS. D. Product Data sheets showing compliance with specified PMCS and Application Modules. E. The following sample screens (Note: For purpose of submittal documentation, screens are not required to be job specific. They should be examples similar to the actual screens to be provided.): 1. Site plan 2. Animated one-line diagrams for a switchgear lineup including breaker status 3. Tabular data for monitored devices 4. Typical Waveform Capture 5. Automated Power Quality Reports 6. Typical Waveform Record Harmonic Analysis 7. Alarms Screen 8. Typical Historical and Real Trend 9. Event log screen 10. System Health Monitor Alarm Screens 11. Generator Control Panel (GCP) overview screen 12. PLC tabular screen 13. UPS tabular data screen 14. PDU tabular data screen 15. Battery Monitor status screen 1.07 OPERATION AND MAINTENANCE MANUAL A. Manufacturer shall provide copies of installation, operation and maintenance procedures to the owner for the PMCS and Application Modules. B. Deliver one copy of the software to the customer simultaneous with the system hardware and software delivery. ELECTRICAL POWER MONITORING AND CONTROL 16215 - 1 ELECTRICAL POWER MONITORING AND CONTROL GE Consumer and Industrial C. Deliver copies of the system instruction manuals in conjunction with the training requirements of this section. 1.08 QUALITY ASSURANCE (QUALIFICATIONS) A. Manufacturer shall be able to demonstrate experience and expertise in the manufacture and assembly of electrical distribution systems and PMCS software. B. The PMCS vendor shall provide a full time telephone technical help center for customers. 1.09 FACTORY ACCEPTANCE (TESTING) A. System shall be 100% tested through simulation of Modbus RTU and Modbus over IP before installation at the owner’s site. 1.10 DELIVERY, STORAGE, AND HANDLING A. Deliver, store, protect, and handle products in accordance with recommended practices listed in manufacturer’s Installation and Maintenance Manuals. B. Deliver one copy of the software and copies of system instruction manuals on CD ROM C. Inspect and report concealed damage to carrier within specified time. 1.11 WARRANTY A. Manufacturer warranty for the PMCS shall be 1 year from date of installation or 18 months from date of purchase, whichever occurs first. PART 2 PRODUCTS 2.01 MANUFACTURER A. General Electric Company products have been used as the basis for design. Other manufacturers’ products of equivalent quality and operating features may be acceptable, at the Engineer’s discretion; if they comply with all requirements specified or indicated in the Contract documents. All component parts should be based on open communication protocols and standards so those components from different manufacturers can be combined to build an integrated Power Management Control System (PMCS). 2.01 POWER QUALITY METER CHARACTERISTICS (EPM 9650) A. Power Quality meters shall continuously monitor the three-phase, WYE or Delta power system. B. Power meter shall be UL listed, MV 90 compatible, multi-function 3-phase solid-state unit with ability to continuously monitor the three-phase, WYE or Delta power system. Meter shall have a four-year warranty. C. The meter shall have four (4) independent voltage inputs and four (4) independent current inputs of the stated capacity. Voltage input shall exceed IEEE 37.90.1. Current input shall be rated for 5 amps with a continuous input capability of 10 amps. Current inputs shall be solid U-Bolt stud inputs with a 10 second over-current rating of 100 amps and a 1-second over-current rating of 300 amps. D. Power meter shall measure and report the following quantities at a minimum: ELECTRICAL POWER MONITORING AND CONTROL 16215 - 1 ELECTRICAL POWER MONITORING AND CONTROL GE Consumer and Industrial 1. Voltage, both phase to neutral and phase to phase, for all three phases; Auxiliary voltage; Phase angles for each voltage relative to each other. 2. Current, phase A, B, C, N-measured, and N-calculated; Phase angles for each current relative to voltages. 3. Watts (total and per phase), VARs (total and per phase), VA (total and per phase), Power Factor (total and per phase) and Frequency 4. Accumulated Watt-hr, VA-hr, and VAR-hr. 5. Power demand shall be calculated using four (4) different averaging methods: Thermal Average, Fixed Window Average, Sliding Window Average, and Predicted Average. Values for all averaging intervals must be available simultaneously. 6. Power meter shall provide updates of all voltage and current readings at intervals of 1 cycle, 50 milliseconds, and 1 second. Readings shall be available for both metering and control. All specified readings shall be made available via the RS-485 ports over the Modbus as well as Ethernet. 7. Power meter shall provide time-stamped maximum and minimum readings for every measured parameter. 8. Power meter shall provide coincident VAR readings for all maximum Watt readings. E. Power meter shall provide the following accuracies: 1. Power meter shall meet ANSI C12.20 and IEC 687 accuracy requirements. 2. Voltage accuracy shall be 0.01% or better for the 1-second readings 3. Current accuracy shall be 0.025% or better for the 1-second readings. 4. Power and energy accuracy shall be 0.04% or better at unity PF 5. Frequency accuracy shall be 0.001 Hz or better. F. Power meter shall provide multiple configurable digital communication ports and support multiple open protocols. G. Power meter shall be fully web based and should be able to transmit its measured data over the web using customer’s Local Area Network. Data shall be accessible at any location with Web connection through the use of standard Web Browser. No additional software shall be required to read data. H. Power meters shall also be capable of acting as web host for the meters/trip units etc connected to the meter. Power meter shall make the measured data from the connected devices (up to eight) available over the web. I. Meter shall have an Ethernet port and a 56K internal modem as an available option. J. Meter shall offer communications using both Modbus and DNP 3.0 open protocols simultaneously as standard configurations. All instantaneous data, logged data, event data, power quality analysis and waveform information shall be available using these open protocols. K. Meter shall include four (4) independent, digital communication ports. Each port shall be RS-485 architecture. Port 1 shall be user selectable as either RS232 or RS-485. L. Power meter shall provide sequence of events capture and recording. ELECTRICAL POWER MONITORING AND CONTROL 16215 - 1 ELECTRICAL POWER MONITORING AND CONTROL GE Consumer and Industrial M. Meter shall have at least eight high-speed status inputs for capturing external events with one millisecond resolution, monitored at a user set rate of 1- 8 samples per millisecond. All changes in status shall be time stamped and stored. N. High-speed status inputs shall be able to trigger waveform recording to the waveform log. O. Power meter shall provide a separate IRIG-B input for time synchronizing to GPS time signal. P. Power meter shall provide external display(s), up to 4, to accommodate access to readings locally and/or up to 4000 feet remotely. Display(s) shall be LCD Touch-Screen and/or LED Display. Q. The LCD Display shall display: 1. Time of Use Readings 2. Real-Time Readings 3. Phasor Diagrams 4. Harmonic Spectrum (to the 127th order) 5. Real-Time Waveforms (all channels) 6. Up to 8 different meters simultaneously 7. Capable of interfacing with up to 168 EPM 9650 meters by addressing functions R. Power meter shall be equipped with 4MB non-volatile RAM for recording logs and programming information. In the event of loss of control power, data stored in memory shall be retained for at least 10 years. Meter shall store historical trending data, power quality data and waveform recordings in memory S. The power meter shall sample waveform at user configurable rates of 16 to 512 samples per 60 Hz cycle. All voltage and current readings shall be recorded using a 16-bit A/D converter. Power meter shall measure harmonics up to the th 255 order for each voltage and current. Real-time harmonics are resolved to the th 128 for all voltages and currents. T. Power meter shall capture, record and date/time stamp up to 1024 CBEMA quality events. U. Meter shall hold at least 96 seconds of waveform recording in non-volatile memory. Each record shall be a minimum of 8 cycles in duration at the highest sample rate or 64 cycles in duration at the lowest sample rate. V. Waveforms shall be recorded with time resolution to within one millisecond. W. A waveform record shall be taken whenever the RMS value of voltage or current exceeds user-set limits. X. Power meter shall have expandable external auxiliary I/O capability. This capability shall allow the power meter to operate as an RTU for control and data acquisition. Y. Power meter shall be appropriately constructed to provide long life in abusive physical and electrical environments. The meter shall operate successfully between -40C to +70C. Z. Power meter shall be General Electric / model: EPM9650 with 4 Meg memory. 2.02 ELECTRONIC TRIP UNITS CHARACTERISTICS ELECTRICAL POWER MONITORING AND CONTROL 16215 - 1 ELECTRICAL POWER MONITORING AND CONTROL GE Consumer and Industrial A. Each specified circuit breaker shall have an electronic trip unit that will display and optionally communicate the following information to an operator or to the PMCS. B. Provide the following breaker/trip unit information to the PMCS network: 1. Breaker frame size and trip unit options. 2. Breaker sensor rating. 3. Rating plug. 4. Breaker status information. 5. Type of last trip (overload, short circuit, ground fault) 6. Breaker trip counters (Inst., short time, long time, ground fault) 7. Trip unit setup C. Provide the following metering information: 1. RMS current per phase 2. RMS voltage (line to line and line to neutral) 3. Real, reactive and apparent power. 4. Power factor 5. Frequency 2.03 GENERATOR PROTECTIVE RELAY CHARACTERISTICS A. Each generator will be protected by a generator protection relay similar to the GE Multilin SR 489 relay. This relay will be able to communicate status and electrical power information to the PMCS system using Modbus RTU protocol communications port. All measured quantities can be viewed on the front panel display, through the communication ports or through one of the 4 optional analog outputs. As a minimum the following information can be monitored or viewed: 1. Generator current per phase 2. Generator voltage 3. Generator Power: kW, Kvar, kVA 4. Energy use MWh Mvarh 5. Power factor, 6. Demand and peak demand for current and power (kW, kvar, kVA) 7. Frequency 8. 4 each optional analog input 9. Generator temperature, (12 each RTD inputs) 10. Event Recorder. Capture and store the 40 events, recording time, date, and cause. 11. Waveform Capture 2.04 UPS CHARACTERISTICS A. Each UPS will provide information to the PMCS either through a Modbus RTU communications port or dry contact discrete signals and 4-20 ma analog signals. As a minimum the following information can be monitored or viewed: 1. UPS bypass volts (line-line, all phases) 2. UPS critical bus voltage (Line-line & line-neutral, all phases) 3. UPS critical bus current (all phases) 4. UPS critical bus frequency 5. UPS critical bus KVA ELECTRICAL POWER MONITORING AND CONTROL 16215 - 1 ELECTRICAL POWER MONITORING AND CONTROL GE Consumer and Industrial 6. UPS critical bus KW 7. Thirty-two (32) UPS status points 2.05 PDU CHARACTERISTICS A. Each PDU will provide information to the PMCS either through a Modbus RTU communications port or dry contact discrete signals and 4-20 ma analog signals. As a minimum the following information can be monitored or viewed: 1. PDU input volts (line-line, all phases) 2. PDU output volts (Line-line & line-neutral, all phases) 3. PDU output current (all phases) 4. PDU output frequency 5. PDU output KVA 6. PDU output KW 7. Sixteen (16) PDU status points 2.06 PMCS NETWORK A. The communications layer shall be designed to collect data over many topographies including modem, Ethernet, Internet, etc. The communications software shall support both solicited and unsolicited data input from Intelligent Electronic Devices. Software for identifying and adding new monitors to the system shall be included. B. PMCS Ethernet network should allow the owner the capability to program and troubleshoot PLC’s and other IED devices over the network. C. Ethernet switches shall be managed, industrial hardened switches using the appropriate cable to handle bandwidth and speed in the case of copper and for fiber optics. 2.07 PMCS INTERFACE TO BUILDING MANAGEMENT SYSTEMS (BMS) A. PMCS shall be built on a platform that can support the capabilities to be a full Building Management System, with capabilities of climate/temperature control, video surveillance, fire and security alarm system, and lighting control. B. The high-speed network utilized by the PMCS system shall permit easy interface with other the Building Management Systems (BMS). Data located in the power monitoring devices and PLC registers, and associated inputs/outputs shall be made available to the BMS vendor via the PMCS host computer. Data from the PMCS may be accessed using OPC or ODBC technology, as well as DDE legacy technology. C. Hardware and software required by a BMS to retrieve data from the PMCS data highway shall be the responsibility of the BMS vendor. PMCS supplier shall provide all required system output configuration required for the BMS vendor to read information. 2.08 PMCS SOFTWARE DESCRIPTION A. The PMCS shall be supplied with user-friendly application software suitable for operation on personal computer workstations. The workstations shall serve as central control stations by monitoring the devices in the system, recording events, indicating alarm conditions, and displaying and logging device data. ELECTRICAL POWER MONITORING AND CONTROL 16215 - 1 ELECTRICAL POWER MONITORING AND CONTROL GE Consumer and Industrial 2.09 DATA COLLECTION SOFTWARE A. The data collection software will be a multi-threaded application to allow for the simultaneous collection of data from multiple monitors. 2.10 DATA COLLECTION A. The software will collect all data recorded by the IED’s. This will involve retrieving data from the various stored logs to include historical or trend logs, power quality logs and waveform logs. Each meter location shall have its own data collection frequency. The power quality meter and data collection configuration information shall be stored in a relational database. Error checking will be used to verify data integrity. All data will be stored in a comma separated file format. 2.11 DATABASE A. The database shall be an open architecture ODBC compliant database for the storage of all measurement data. The software and database schema shall be compatible with ODBC compliant database engines to include SQL Server, Oracle, and Access. B. Self-documenting, tagged structures shall not be acceptable. C. The software will include an API for the database. 2.12 TIME SYNCHRONIZATION A. The system data collection layer shall use a GMT standard to account for time zones and time changes. The collected data will use the time stamp of the monitor itself and will not be adjusted by the System. The ability to incorporate devices that can be time synchronized by the PC clock or an IRIG-B signal shall be available. The System shall be capable of synchronizing the monitor clocks with a degree of accuracy dependent upon the communications topography using Internet based time synchronization services. 2.13 ALARM - EVENT NOTIFICATION A. The system shall provide a high level of flexibility to alarm and notify personnel when a user-defined event has occurred. For each monitor site, the ability shall be provided to select an “event parameter” a high and low limit, and an “action”. The Bidder shall provide details of the proposed system’s capabilities or make recommendations of the options available to provide this capability. B. The system shall accommodate a unique text message defined by the user to describe the alarm condition and the monitor. Upon alarm, one or more designated people will be paged and/or emailed with the text message. The system should accommodate numeric and alphanumeric pagers. All alarms will be recorded in an alarm log. All software required to do paging must be included. C. The system shall also provide for automatic report generation triggered by an alarm condition. All report generated by the system shall be available to be triggered by an alarm condition. D. The system shall provide a separate Event log and viewer, allowing the user to sort the events by time stamps, event type, etc. The event log file shall be ELECTRICAL POWER MONITORING AND CONTROL 16215 - 1 ELECTRICAL POWER MONITORING AND CONTROL GE Consumer and Industrial capable of holding at least 1,000 events, the date/time of the event, and a descriptive text. 2.14 GRAPHICAL USER INTERFACE A. Software shall be provided with graphical interface to view the archived data, both tabular and waveforms. Multiple waveform events representing a continuous waveform should be appended and displayed as a single multi-cycle waveform event. B. The ability to produce summary graphs of CBEMA charts and time plots shall be provided with the ability to jump to specific events of interest. The specific charts required include CBEMA, ITIC, Sag Frequency Distribution, Harmonic Distribution, and time plots for each parameter measurement by the monitor to include energy, demand, PF, VARS, VA, THD, W, and unbalance. C. The charting and graphing software shall not be device dependent. It shall be able to provide charting and graphing of all available power monitors available today as well as those that will be introduced in the future. It shall also be capable of plotting and charting non-power monitor kinds of data to include analog type data (temperature, flow, etc., as well as binary information (breaker open closed data). D. For each cycle of waveform data displayed, the software will compute and display simultaneously power parameters to include W, VA, VARS, THD, any single harmonic, V or A unbalance, Vrms, Arms, and PF. 2.15 COMPUTER HEALTH MONITORING SOFTWARE A. Computer Health monitoring software shall continuously monitor the functioning of the computer as well as the related system software. In case of a problem, the software shall automatically generate alarm for predictive as well as diagnostic maintenance. 2.16 INTELLIGENT ASSISTANCE Power Quality ANALYSIS SOFTWARE A. Software shall perform automated power quality audits and produce reports using Artificial Intelligence to pin point fault causes and possible preventive measures The software shall rank each recorded event in terms of its severity i.e. its potential destructive impact on sensitive electronic loads. It shall also determine the direction of the source of the disturbance as upstream or downstream from the monitoring location. The software shall attempt to determine the specific source of the disturbance, the equipment it may affect, and offer a generally accepted solution for the problem. B. Software shall be able automatically conduct energy audits and send reports in simple format through the email or fax. The output of the analysis shall be automatically generated report that clearly explains the results of the analysis in text and graphics. C. WEB CAPABILITIES 1.The PMCS system shall be web enabled to allow clients and Customer engineers to view reports generated by the system and to allow Customer engineers to have full access to the monitor data. The web software will be provided by the supplier and have the following features: a. Graphics including Flash components as agreed by Customer. ELECTRICAL POWER MONITORING AND CONTROL 16215 - 1 ELECTRICAL POWER MONITORING AND CONTROL GE Consumer and Industrial b. Database driven security levels allowing access to web reports and data. c. Ability to determine available reports and to offer the user only those available reports. d. Links as determined by Customer 2.17 PMCS SOFTWARE A. PMCS Software package shall include: B. Operate in multitasking, multi-user environment. Windows 2K compliant C. Log PMCS data to a hard disk at user-specified intervals and provide exporting functions to allow usage of the logged data by other software products. Be able to export data to other Microsoft ® Windows applications via the OPC server or Dynamic Data Exchange (DDE) technology, comma separated variable (CSV) format or COMTRADE format. D. Manage Alarm Function. Annunciates and logs alarm messages from discrete input and controls outputs, according to programmable security access. Provides visual, audible and/or required acknowledgment. E. Report the status inputs and outputs, transformer temperature monitor relays (fan, alarm, and emergency shutdown relays), electronic trip unit status, status I/O associated with programmable logic controllers, etc. F. Include harmonic information in the graphic waveform displays for power quality meters including total harmonic distortion (THD), RMS magnitudes, peak values, crest factors (CF), magnitudes of the individual harmonics, telephone interference factor (TIF), etc. Plot and apply fast Fourier analysis to ac voltage and current waveforms, captured by network devices, for accurate viewing of harmonic content up to the 128th order; G. Standard reports to simplify routine printouts of various data formats. Reports shall contain information as described within this specification. H. Password-protected. I. In conjunction with a programmable logic controller, provide supervisory control as indicated above under “System Description”; J. Be able to interface to Building Management System or other devices to expand the role of the PMCS system K. Systems shall be capable of providing context sensitive on-line help. L. Define and initiates load-shedding schemes based on time schedules and/or in response to set points. M. Software shall contain interactive color-graphics as follows: 1. One-Line electrical distribution drawing as shown on contract documents. 2. Accurate graphical representation of each monitored device. 3. Define and view trends for any of the parameters available via the metering devices on the network. 4. Alarms sorted by date, time, device type or type of alarm. 5. View captured and recorded waveforms. 6. Provide capabilities for Annunciator panel creation. 7. Custom screens and reports. 8. Diagnostic system analysis reports. 2.18 COST ALLOCATION MODULE ELECTRICAL POWER MONITORING AND CONTROL 16215 - 1 ELECTRICAL POWER MONITORING AND CONTROL GE Consumer and Industrial A. Cost allocation module to provide the following: 1. WEB based solutions capable of standalone operation. 2. Pinpoint when and by whom peak demands are set. 3. Find out how much energy individual tenants or departments are using. 4. Allocate utility costs per building, floor, shift, production line, process step or department. 5. Benchmark departments on energy savings and motivate them to attain energy savings goals. 6.Create virtual meters and define cost centers. 7.Provide data in SQL database. 8. Store data in CSV format. 9. Allow for aggregation of numerous sites at common location. 10. Import or generate real-time pricing structures. 11. Manage up to 50 different rate structures at the same time. 2.19 COMPUTER HARDWARE REQUIREMETNS FOR RUNNING SOFTWARE A. The PMCS system shall have a minimum of one Host Computer (PC). All computers supplied shall be complete with Application Software and license as specified. The computers shall be pre-configured with all software and configuration files by the vendor and ready to connect and operate when delivered to the job site. B. Host Computer / Server Computer / Mission Critical Computer shall serve as central control station by monitoring the devices in the system, recording events, indicating alarm conditions, and displaying and logging device data. This Server/Mission Critical Computer shall have the following minimum requirements: 1. Processor: Dual Core Intel Xeon Processor, 2.33GHz or faster, 2. Additional Processor (when required): dual core Intel Xeon processor, 2.33GHz or faster. 3. Memory: 2GB RAM (additional memory if required by the HMI vendor) 4. Operating System: Windows Server 2003R2 or Windows XP Professional – SP25. 6. Primary Hard Drive: 80GB (optional 146GB hard drive) 9. CD/DVD Drive: 24X IDE CD-RW/DVD ROM drive 10. Mouse: optical two-button mouse, USB 11. Network Adapter: Intel PRO 1000PT dual port server adapter 12. Power Supply: Energy Smart redundant power supply with straight cord C. Viewer Computer (when required) shall meet the following requirements: 1. Processor: Intel Pentium Processor 1GHz or more 2. Memory: 512GB RAM (additional memory if required by the HMI vendor) 3. Operating System: Genuine Windows XP Professional, SP25. or Windows Server 2003R2 4. Primary Hard Drive: 80GB (require minimum available space 700Mb on system drive and 40GB available space on installation drive. 5. CD/DVD Drive: 24X CDRW/DVD Combo 6. Mouse: optical two-button mouse, USB ELECTRICAL POWER MONITORING AND CONTROL 16215 - 1 ELECTRICAL POWER MONITORING AND CONTROL GE Consumer and Industrial 7. Network Adapter: Intel PRO 1000PT dual port server adapter 8. Video capable of displaying 16-bit 1024 x 768 resolution minimum (1280x1024 resolution recommended) D. Printer: 1. Network capable laser printer 2. Parallel port line printer for alarms PART 3 EXECUTION 3.01 INSTALLATION A. Coordinate with the manufacturer and electrical contractors to insure all junction boxes, repeaters and other appurtenances necessary for a complete, operational PMCS system and network are provided. B. All power quality meters, electronic trip units, transformer temperature monitors, motor protection devices, shall be installed by the manufacturer within the supplied electrical equipment for all circuits as indicated by the project drawings. C. All control power, CT, PT, and data communications wire shall be factory-wired and harnessed within the equipment enclosure. D. 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. Splices within cabinets shall not be accepted. 3.02 ON-SITE PMCS START-UP A. Install all HMI software, graphic screens, system configuration information and point databases on the host computer in accordance with PMCS Users Guide. The manufacturer shall provide [] days (including travel and living) of on site startup assistance for system setup and operation of PMCS system. B. Start-up shall include a complete working demonstration of the PMCS with control and monitoring of each device in the system and simulation of all possible operating conditions, which may be encountered. C. After completion of the startup, a customer signoff document will be generated and a closeout meeting will occur. 3.03 ON-SITE PMCS TRAINING A. The project bid shall include [] days of training including travel and living. B. 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. 3.04 PMCS SERVICE AGREEMENT OPTIONS: A. The PMCS supplier shall provide the following Service Agreement Options. The customer shall have the flexibility to select from the below listed service offerings. ELECTRICAL POWER MONITORING AND CONTROL 16215 - 1 ELECTRICAL POWER MONITORING AND CONTROL GE Consumer and Industrial 1. One (1) or Three (3) year service support to include software upgrades, Technical Specialist phone support, System Operational status reviews through remote system access. 2. One (1) year System Audits and consulting services 3. Technical Phone Support from PMCS system specialists (40 hours or more per year) ELECTRICAL POWER MONITORING AND CONTROL 16215 - 1