251010-2010-02 Power Metering.pdf

02-10 598-19-112 Replace Underground 15kV Feeder Separable Connectors and Transformers Eugene J. Towbin Healthcare Center North Little Rock, AR

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SECTION 25 10 10

ADVANCED UTILITY METERING SYSTEM

PART 1 - GENERAL

1.1 DESCRIPTION

A. This Section includes the following for the advanced metering of the systems of the facility. The metered systems include the electrical power, natural gas distribution, fuel gas and fuel oil, steam, steam condensate, chilled water, heating water, domestic water, recovered water and makeup water systems. The metering systems in each facility are part of a Corporate-Wide utility metering system, rendering the VA accurate and automated metering of its facilities’ energy and water flows. Metering systems are comprised of:

1. PC-based workstation(s) or server(s) and software.

2. Communication network and interface modules for RS-232, RS-485, Modbus TCP/IP, IEEE 802.3 data transmission protocols.

3. Electric meters.

4. Volumetric flowmeters, temperature sensors and pressure transducers.

5. Mass flowmeters.

1.2 RELATED WORK

A. Section 26 05 11, REQUIREMENTS FOR ELECTRICAL INSTALLATIONS: General electrical requirements and items that are common to more than one section of Division 26.

B. Section 26 05 26, GROUNDING AND BONDING FOR ELECTRICAL SYSTEMS:

Requirements for personnel safety and to provide a low impedance path for possible ground fault currents.

1.3 DEFINITIONS

A. AMR: Automatic meter reading is the technology of automatically collecting consumption, diagnostic, and status data from water and energy metering devices (water, gas, electric, steam) and transferring that data to a central database for billing, troubleshooting, and analyzing.

B. AUMS: Advanced Utility Metering System: the system described by this

Section.

C BACnet: BACnet is a Data Communications Protocol for Building

Automation and Control Networks. It is defined by ASHRAE/ANSI Standard

135 (ISO 16484-5) standard protocol.

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D. Data Over Cable Service Interface Specification (DOCSIS): an international standard defining communications and operation support interface requirements for a data over cable system, by the Cable

Television Laboratories, Inc. consortium

E. Data Head (on meters): converts analog and pulse signals to digital signals for transmission to the Site Data Aggregation Device. Also provides for limited storage of the digital signals.

F. Device Accuracy: accuracy in this section is based on actual flow, not full scale or full range. Device accuracy measures the conversion of flow information to analog or pulse signals.

G. Ethernet: Local area network, based on IEEE 802.3 standards.

H. Firmware: Software (programs or data) that has been written onto read-only memory (ROM). Firmware is a combination of software and hardware.

Storage media with ROMs that have data or programs recorded on them are firmware.

I. Gateway: Bi-directional protocol translator connecting control systems that use different communication protocols.

J. GB: gigabyte. When used to describe data storage, "GB" represents

1024 megabytes.

K. HTML: Hypertext markup language.

L. I/O: Input/output.

M. KB: Short for kilobyte. When used to describe data storage, "KB" represents 1024 bytes.

N. KY Pulse: A term used by the metering industry to describe a method of measuring consumption of electricity that is based on a relay changing status in response to the rotation of the disk in the meter.

O. LAN: Local area network. Sometimes plural as "LANs."

P. LCD: Liquid crystal display.

Q. LonMark: An association comprising of suppliers and installers of

LonTalk products. The Association provides guidelines for the implementation of the LonTalk protocol to ensure interoperability through Standard implementation.

R. LonTalk: An open standard protocol developed by the Echelon Corporation that uses a “Neuron Chip” for communication.

S. LonWorks: Network technology developed by the Echelon Corporation.

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T. Low Voltage: As defined in NFPA 70 for circuits and equipment operating at less that 50 V or remote-control, signaling and power-limited circuits.

U. MB: megabyte. When used to describe data storage, "MB" represents

1024 kilobytes.

V. Mbps: Megabytes per second, equal to 8 megabits per second

W. Modbus TCP/IP: An open protocol for exchange of process data.

X. Monitoring: Acquisition, processing, communication, and display of equipment status data, metered electrical parameter values, power quality evaluation data, event and alarm signals, tabulated reports, and event logs.

Y. OTDR: Optical Time Domain Reflectometer. A test instrument that analyzes the light loss in an optical fiber. Used to find faults, splices and bends in the line, it works by sending out a light pulse and measuring its reflection. Such devices can measure fiber lines that are longer than 150 miles

Z. PC: Personal computer

AA.PICS, Protocol Implementation Conformance Statement: A written document that identifies the particular options specified by BACnet that are implemented in a device.

BB.REO: Resident Engineer Office: the VA office administering the construction contract.

CC.Reporting Accuracy: this is the root-mean-square sum of all of the metering devices’ inaccuracies: measurement inaccuracy, mechanical inaccuracy, analog-to-digital or pulse integration inaccuracy, etc., up to the meter’s data head.

DD.rms: Root-mean-square value of alternating voltage, which is the square root of the mean value of the square of the voltage values during a complete cycle.

EE.Router: A device that connects two or more networks at the network layer.

FF.RS-232: A Telecommunications Industry Association standard for asynchronous serial data communications between terminal devices.

GG.RS-485: A Telecommunications Industry Association standard for multipoint communications using two twisted-pairs.

HH.TB: terrabyte. When used to describe data storage, "TB" represents

1024 gigabytes.

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II.TCP/IP: Transport control protocol/internet protocol.

JJ.Turn-down: the maximum flow divided by the minimum flow through a meter; used along with accuracy requirements. For example, a meter shall be accurate to within 2% of actual flow with throughout a 20:1 turndown

KK.THD: Total harmonic distortion.

LL.UPS: Uninterruptible power supply; used both in singular and plural context.

MM.UTP: Unshielded twisted pair cabling, used to limit crosstalk and electromagnetic interference from the environment

NN.WAN: Wide area network.

1.4 QUALITY ASSURANCE

A. Installer Qualifications: Manufacturer's authorized representative who is trained and approved for installation of units required for this

Project.

B. Manufacturer Qualifications: A firm experienced at least three years in manufacturing and installing power monitoring and control equipment similar to that indicated for this Project and with a record of successful in-service performance.

C. Electrical Components, Devices, and Accessories: Listed and labeled as defined in NFPA 70, Article 100, by a testing agency, and marked for intended use.

D. System Modifications: Make recommendations for system modification in writing to the VA. No system modifications shall be made without prior written approval of the VA. Any modifications made to the system shall be incorporated into the Operations and Maintenance Instructions, and other documentation affected. Provide to the VA software updates for all software furnished under this specification during this contract’s construction and verification periods and for the first two years after government acceptance. All updated software shall be verified as part of this contract.

1.5 PERFORMANCE

A. The advanced utility metering system shall conform to the following:

1. Site Data Aggregation Device Graphic Display: The system shall display up to 4 graphics on a single screen with a minimum of (20) dynamic points per graphic. All current data shall be displayed within (10) seconds of the request.

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2. Site Data Aggregation Device Graphic Refresh: The system shall update all dynamic points with current data within ten seconds. Data refresh shall be automatic, without operator intervention.

3. Meter Scan: All changes of metered values shall be transmitted over the high-speed network such that any data used or displayed at a controller or Site Data Aggregation Device will be current, within the prior ten seconds.

4. Alarm Response Time: The maximum time from when meter goes into alarm to when it is annunciated at the workstation shall not exceed ten seconds.

5. Reporting Accuracy: Listed below are minimum acceptable reporting accuracies for all values within the below minimum turn-down envelope reported by the meters:

Measured Variable Units Measured

Minimum Turn-Down of Meter

Reporting Accuracy (Note 1)

Electricity V, A, W, etc.

n/a ±0.5% of measured value

Table 1.5: Meter Performance Criteria Table Notes:

1. This table shows reporting accuracy, not merely the meter’s accuracy. Reporting accuracy includes meter accuracy and data conversion accuracy. See Article 1.3 in this Section for definition. Accuracy is shown against the measured value, not against the full range of the meter.

2. kW: kilowatt

1.6 WARRANTY

A. Labor and materials for advanced utility metering systems shall be warranted for a period as specified under Warranty in FAR clause

52.246-21.

B. Advance utility metering system failures during the warranty period shall be adjusted, repaired, or replaced at no cost or reduction in service to the owner. The system includes all computer equipment, transmission equipment, and all sensors and metering devices.

1.7 SUBMITTALS

A. Product Data: for each type of product indicated, Attach copies of approved Product Data submittals for products (such as flowmeters, temperature sensors and pressure transmitters, switchboards and

25 10 10 - 6 switchgear) that describe advance utility metering features to illustrate coordination among related equipment and utility metering and control.

B. Shop Drawings: include plans, elevations, sections, details, and attachments to other work.

1. Outline Drawings: Indicate arrangement of meters, components and clearance and access requirements. Clearly identify system components, internal connections, and all field connections.

2. Block Diagram: Show interconnections between components specified in this Section and devices furnished with power distribution system components. Indicate data communication paths and identify networks, data buses, data gateways, concentrators, and other devices to be used. Describe characteristics of network and other data communication lines.

3. Detail equipment assemblies and indicate dimensions, weights, loads, required clearances, method of field assembly, components, and location and size of each field connection.

4. Wiring Diagrams: Power, signal, and communications wiring.

Coordinate nomenclature and presentation with a block diagram. Show all communications network components and include a communications single-line diagram indicating device interconnection and addressing information for all system devices. Identify terminal blocks used for interconnections and wire type to be used.

5. UPS sizing calculations for workstation.

C. Software and Firmware Operational Documentation:

1. Self-study guide describing the process for setting equipment's network address; setting Owner's options; procedures to ensure data access from any PC on the network, using a standard Web browser; and recommended firewall setup.

2. Software operating and upgrade manuals.

3. Software Backup: On a compact disc, complete with Owner-selected options.

4. Device address list and the set point of each device and operator option, as set in applications software.

5. Graphic file and printout of graphic screens and related icons, with legend.

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6. "Quick-Start" guide to describe a simple, three-step commissioning process for setting the equipment’s Ethernet address, and ensuring trouble-free data access from any PC on the network, using a standard web browser.

D. Software Upgrade Kit: For Owner to use in modifying software to suit future utility metering system revisions.

E. Firmware Upgrade Kit: For Owner to use in modifying firmware to suit future power system revisions or advanced utility metering system revisions. Firmware updates, and necessary software tools for firmware updates, shall be downloadable from the internet. VA shall be able to update firmware, in equipment, without removing device from the equipment. VA shall be capable of updating firmware over the utility metering communication network or through local communication ports on the device.

F. Software licenses and upgrades required by and installed for operating and programming digital and analog devices.

G. Qualification Data: For installer and manufacturer

H. Other Informational Submittals:

1. System installation and setup guides, with data forms to plan and record options and setup decisions.

I. Revise and update the Contract Drawings to include details of the system design. Drawings shall be on 17 by 11 inches sheets. Details to be shown on the Design Drawing include:

1. Details on logical structure of the network. This includes logical location of all network hardware.

2. Manufacturer and model number for each piece of computer and network hardware.

3. Physical location for each piece of network or computer hardware.

4. Physical routing of LAN cabling.

5. Physical and qualitative descriptions of connectivities.

1.8 CLOSEOUT SUBMITTALS

A. Operation and Maintenance Data: For advanced utility metering system components and meters, to include in emergency, operation, and maintenance manuals. Include the following:

1. Operating and applications software documentation.

2. Software licenses.

3. Software service agreement.

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4. PC installation and operating documentation, manuals, and software for the PC and all installed peripherals. Software shall include system restore, emergency boot compact disks, and drivers for all installed hardware. Provide separately for each PC.

5. Hard copies of manufacturer's specification sheets, operating specifications, design guides, user's guides for software and hardware, and PDF files on CD-ROM of the hard-copy submittal.

6. In addition to the copies required by 01 00 00, provide 5 bound paper copies of the Operation and Maintenance Data and two compact disks (CD), with all Instructions as Acrobat PDF files. The pdf files shall identical to the paper copies and shall Acrobat navigation tools including Bookmarks for each Chapter.

7. The advanced utility metering system Operation and Maintenance

Instructions shall include:

a. Procedures for the AUMS system start-up, operation and shut-down.

b. Final As-Built drawings, including actual LAN cabling routing shown on architectural backgrounds.

1) IP address(es) as applicable for each piece of network hardware.

2) IP address for each computer server, workstation and networked printer.

3) Network identifier (name) for each printer, computer server and computer workstation.

4) CEA-709.1B address (domain, subnet, node address) for each

CEA-709.1B TP/FT-10 to IP Router.

c. Routine maintenance checklist, rendered in a Microsoft Excel format. The routine maintenance checklist shall be arranged in a columnar format. The first column shall list all installed devices, the second column shall list each device’s node identifier/address, the third column shall describe each device’s physical location, the fourth column shall state the maintenance activity or state no maintenance required, the fifth column shall state the frequency of the maintenance activity, frequency of calibration and the sixth column for additional comments or reference.

d. Qualified service organization list.

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e. In addition to the requirements in Section 01 33 23, the submittal shall include manufacturer Installation Requirements.

f. Include complete instructions for calibration of each meter type and model.

g. Start-Up and Start-Up Testing Report.

h. Performance verification test procedures and reports.

i. Preventive Maintenance Work Plan.

j. In addition to factory-trained manufacturers' representatives requirements in 01 00 00, provide signed letter by factory-trained manufacturers' representatives stating that the system and components are installed in strict accordance with the manufacturers’ recommendations.

B. Field quality-control test reports.

1.9 LICENSING AGREEMENT

A. Licenses procured as part of this work become the property of the government upon acceptance of the work. Licenses shall have no expiration.

B. Technical Support: Beginning with Government Acceptance, provide software support for one year.

C. Upgrade Service: Update software to latest version at Project completion. Install and program software upgrades that become available within two years from date of Government Acceptance.

Upgrading software shall include the operating systems. Upgrade shall include new or revised licenses for use of software.

1. Provide 30-day notice to Owner to allow scheduling and access to system and to allow Owner to upgrade computer equipment if necessary.

1.10 MAINTENANCE AND SERVICE

A. Preventive Maintenance Requirements: provide a preventative maintenance plan with attached procedures indicated by meter and component manufacturers. Perform maintenance procedures for a period of 1 year after government acceptance, at frequencies and using procedures required by the meter and component manufacturers.

B. Service Call Reception

1. A VA representative will advise the Contractor by phone or in person of all maintenance and service requests, as well as the classification of each based on the definitions specified. A

25 10 10 - 10 description of the problem or requested work, date and time notified, location, classification, and other appropriate information will be placed on a Service Call Work Authorization Form by the VA.

2. The Contractor shall have procedures for receiving and responding to service calls during regular working hours. A single telephone number shall be provided for receipt of service calls during regular working hours. Service calls shall be considered received by the

Contractor at the time and date the telephone call is placed by the

VA.

3. Separately record each service call request, as received on the

Service Call Work Authorization form. Complete the Service Call Work

Authorization form for each service call. The completed form shall include the serial number identifying the component involved, its location, date and time the call was received, nature of trouble, names of the service personnel assigned to the task, instructions describing what has to be done, the amount and nature of the materials to be used, the time and date work started, and the time and date of completion.

4. Respond to each service call request within two working hours. The status of any item of work must be provided within four hours of the inquiry during regular working hours, and within sixteen hours after regular working hours or as needed to repair equipment.

1.11 SPARE PARTS

A. Furnish spare parts described below that match products installed and that are packaged with protective covering for storage and identified with labels describing contents.

1. Addressable Relays: One for every ten installed. Furnish at least one of each type.

2. Data Line Surge Suppressors: One for every ten of each type installed. Furnish at least one of each type.

B. Furnish spare parts shall not be used for any warranty-required remediation.

1.12 APPLICABLE PUBLICATIONS

A. Publications listed below (including amendments, addenda, revisions, supplements, and errata) form a part of this specification to the

25 10 10 - 11 extent referenced, unless otherwise noted. Publications are referenced in the text by the basic designation only.

B. American Society of Mechanical Engineers (ASME):

B16.1-1998..............Cast Iron Pipe Flanges and Flanged Fittings

B31.1-2007..............Power Piping

B31.8-2007..............Gas Transmission and Distribution Piping

Systems

B31.9-2008..............Building Services Piping

B40.100-1998............Pressure Gauges and Gauge Attachments

C. American Society of Heating, Refrigerating and Air-Conditioning

Engineers

ASHRAE 135-2008.........A Data Communication Protocol for Building

Automation and Control Networks (ANSI)

D. American Society for Testing and Materials (ASTM)

A53-2006................Pipe, Steel, Black and Hot-Dipped, Zinc-Coated, Welded and Seamless

A106-2006...............Seamless Carbon Steel Pipe for High Temperature

Service

E. Consumer Electronics Association (CEA)

709.1B-2002.............Control Network Protocol Specification

709.3-1999..............Free-Topology Twisted-Pair Channel

Specification

852-A-2004..............Tunneling Component Network Protocols Over

Internet Protocol Channels

F. Federal Communications Commission (FCC)

EMC-2002................FCC Electromagnetic Compliance Requirements

G. Institute of Electrical and Electronics Engineers, Inc. (IEEE)

81-1983.................IEEE Guide for Measuring Earth Resistivity, Ground Impedance, and Earth Surface Potentials of a Ground System

100-2000................The Authoritative Dictionary of IEEE Standards

Terms

802.1D-2004.............Media Access Control Bridges

802.2-2003..............Standards for Local Area Networks: Logical Link

Control

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802.3-2005..............Information Technology - Telecommunications and

Information Exchange between Systems. Local and

Metropolitan Area Networks - Specific

Requirements - Part 3: Carrier Sense Multiple

Access with Collision Detection (CSMA/CD)

Access Method and Physical Layer Specifications

(ANSI)

1100-2005...............Recommended Practice for Powering and Grounding

Electronic Equipment (ANSI)

C37.90.1-2002...........Surge Withstand Capability (SWC) Tests for

Relays and Relay Systems Associated with

Electric Power Apparatus

C57.13-2008.............Standard Requirements for Instrument

Transformers

C62.41.1-2002...........Guide on the Surges Environment in Low-

Voltage(1000 V and Less) AC Power Circuits

C62.41.2-2002...........Recommended Practice on Characterization of

Surges in Low-Voltage (1000 V and Less) AC

Power Circuits

H. International Electrotechnical Commission (IEC)

IEC 61000-2005..........Electromagnetic Compatibility (EMC)- Part 4-5:

Testing and Measurement Techniques; Surge

Immunity Test

I. National Electrical Contractors Association

NECA 1-2006.............Good Workmanship in Electrical Construction

J. National Electrical Manufacturers Association (NEMA)

250-2008................Enclosures for Electrical Equipment (1000 Volts

Maximum)

C12.1-2008..............Electric Meters; Code for Electricity Metering

C12.20-2002.............Electricity Meter - 0.2 and 0.5 Accuracy

Classes

C62.61-1993.............Gas Tube Surge Arresters on Wire Line Telephone

Circuits

ICS 1-2008..............Standard for Industrial Control and Systems

General Requirements

K. National Institute of Standards and Technology (NIST)

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800, Part 39-2008.......[DRAFT] Managing Risk from Information Systems:

An Organizational Perspective

800, Part 46-2009.......Guide to Enterprise Telework and Remote Access

Security

800, Part 52-2009.......Recommended Security Controls for Federal

Information Systems and Organizations

(FIPS) 200-2006.........Minimum Security Requirements for Federal

Information and Information Systems

L. National Fire Protection Association (NFPA)

30-08...................Flammable and Combustible Liquids Code

70-2008.................National Electrical Code (NEC)

54-06...................National Fuel Gas Code

85-07...................Boiler and Combustion Systems Hazard Code

101-06..................Life Safety Code

262-2007................Test for Flame Travel and Smoke of Wires and

Cables for Use in Air-Handling Spaces

M. NSF International

14-03...................Plastics Piping Components and Related

Materials

61-02...................Drinking Water System Components-Health Effects

(Sections 1-9)

N. Telecommunications Industry Association, (TIA/EIA)

H-088C3.................Pathway Design Handbook

232-F-2002..............Interface Between Data Terminal Equipment and

Data Circuit-Terminating Equipment Employing

Serial Binary Data Interchange

485-A-2003..............Electrical Characteristics of Generators and

Receivers for Use in Balanced Digital

Multipoint System

568-C.1-2009............Commercial Building Telecommunications Cabling

Standard

606-A-2002..............Administration Standard for the

Telecommunications Infrastructure

607-A-2002..............Commercial Building Grounding (Earthing) and

Bonding Requirements for Telecommunications

O. Underwriters Laboratories, Inc. (UL):

916-2007................Energy Management Equipment

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5085-3-2007.............UL Standard for Safety Standard Low Voltage

1244-2000...............Electrical and Electronic Measuring and Testing

Equipment

1581-2006...............Electrical Wires, Cables, and Flexible Cords

PART 2 - PRODUCTS

2.1 ADVANCED UTILITY METERING SYSTEM

A. Functional Description

1. Meter and record load profiles. Chart energy and water consumption patterns.

a. Calculate and record the following:

1) Load factor.

2) Peak demand periods.

3) Consumption correlated with facility activities.

b. Measure and record metering data for the following:

1) Electricity.

c. Software: calculate allocation of utility costs.

1) Automatically import energy usage records to allocate energy costs.

2) Verify utility bills and analyze alternate energy rates.

d. Electric Power Quality Monitoring: Identify power system anomalies and measure, display, capture waveforms, and record trends and alarms of the following power quality parameters:

1) Voltage regulation and unbalance.

2) Continuous three-phase rms voltage.

3) Periodic max./min./avg. samples.

4) Harmonics.

5) Voltage excursions.

e. System: Report equipment status and power system control.

B. Communications Components and Networks

1. Site Data Aggregation Device and its networked meters shall communicate using BACNet protocol. Backbone shall communicate using

ISO 8802-3 (Ethernet) Data Link/Physical layer protocol and

BACnet/IP addressing as specified in ASHRAE/ANSI 135-2008, BACnet

Annex J.

a. Control products, communication media, connectors, repeaters, hubs, and routers shall comprise a BACnet internetwork.

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Controller and operator interface communication shall conform to

ANSI/ASHRAE Standard 135-2008, BACnet.

b. Each controller shall have a communication port for connection to an operator interface.

2. Network Configuration: High-speed, multi-access, open nonproprietary, industry standard LAN and WAN and Internetworked

LAN.

3. Communication protocol; LANs complying with RS-485 or RS-485 accessed through Ethernet, 100 Base-TX Ethernet, and Modbus TCP/IP.

4. Network Hardware

a. Building Point of Connection Hardware

1) Active equipment and communication interfaces.

2) Switches, hubs, bridges, routers and servers.

b. IP Network Hardware

1) Wire and Cables, copper connectivity devices.

2) Fiber Optic Patch Panel.

3) Fiber Optic Media Converter

4) Ethernet Switch

5) IP Router

5. Communication Security

a. Remote teleworking and remote access of the network shall be through a firewall, at the Site Data Aggregation Device, complying with the requirements associated with Level 1 security in the Federal Information Processing Standard 140-2 (2002), Security Requirements for Cryptographic Modules.

b. Direct access to network shall be restricted as described in

2.4 GROUNDING

A. Ground cable shields, drain conductors, and equipment to eliminate shock hazard and to minimize ground loops, common-mode returns, noise pickup, cross talk, and other impairments. Comply with VA 27 05 26

Grounding and Bonding for Communications Systems and with VA 26 05 26

Grounding and Bonding for Electrical Systems.

2.5 METER COMMUNICATION

A. Provide a BACNet network allowing communication from the meters’ data heads for future connection.

B. Provide data heads at each meter, converting analog and pulsed information to digital information. Data heads shall allow for up to

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24 hours of data storage (including time stamp, measured value, and scaling factor).

1.

1. Environment: Data Head hardware shall be suitable for the conditions ranging from -29°C to 60°C (-20°F to 140°F). Data Heads used outdoors and/or in wet ambient conditions shall be mounted within waterproof enclosures and shall be rated for operation at conditions ranging from -29°C to 60°C (-20°F to 140°F).

2. Provide a local keypad and display for interrogating and editing data. An optional system security password shall be available to prevent unauthorized use of the keypad and display.

3. Serviceability. Provide diagnostic LEDs for power, communication, and processor. All wiring connections shall be made to field-removable, modular terminal strips or to a termination card connected by a ribbon cable.

4. Memory. The building controller shall maintain all BIOS and data in the event of a power loss for at least 72 hours.

5. Immunity to power and noise. Controller shall be able to operate at

90% to 110% of nominal voltage rating and shall perform an orderly shutdown below 80% nominal voltage. Operation shall be protected against electrical noise of 5 to 120 Hz and from keyed radios up to

5 W at 1 m (3 ft).

2.6 ELECTRICAL POWER METERS AND SUB-METERS

A. ELECTRICAL METER APPLICATIONS

1. Energy meters in the advanced utility metering system shall have models available for amperage ranges of 100-2400 amperes.

a. The RS-485 communications shall provide communications links up to 10,000 feet long.

2. Power meters shall be installed as part of the advanced utility metering system.

a. All setup parameters required by the power meter shall be stored in nonvolatile memory and retained in the event of a control power interruption.

b. The power meter may be applied in three-phase, three- or four-wire systems.

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c. The power meter shall be capable of being applied without modification at nominal frequencies of 50, 60, or 400 Hz.

d. The power meter shall provide for onboard data logging, able to log data, alarms, waveforms and events.

B. Physical and Common Requirements

1. Electrical power meters shall be separately mounted, and enclosed in a NEMA 250, Type 3R enclosure. Environmental Conditions: System components shall be capable of withstanding the following environmental conditions without mechanical or electrical damage or degradation of operating capability:

a. Ambient conditions of 0 to 140 deg F dry bulb and 20 to 95 percent relative humidity, noncondensing.

C. Current and voltage ratings:

1. Designed for use with current inputs from standard instrument current transformers with 5-A secondary and shall have a metering range of 0-10 A.

2. Withstand ratings shall be not less than 15 A, continuous; 50 A, lasting over 10 seconds, no more frequently than once per hour;

500 A, lasting 1 second, no more frequently than once per hour.

3. Voltage inputs from standard instrument potential transformers with

120 volt secondary output. The power meter shall support PT primaries through 3.2 MV.

4. The power meter shall operate properly over a wide range of control power including 90-457 VAC or 100-300 VDC.

D. Electrical measurements and calculated values

1. Power meters shall include the following rms Real-Time Measurements:

a. Current: Each phase, neutral, average of three phases, percent unbalance.

b. Voltage: Line-to-line each phase, line-to-line average of three phases, line-to-neutral each phase, line-to-neutral average of three phases, line-to-neutral percent unbalance.

c. Power: Per phase and three-phase total.

d. Reactive Power: Per phase and three-phase total.

e. Apparent Power: Per phase and three-phase total.

f. True Power Factor: Per phase and three-phase total.

g. Displacement Power Factor: Per phase and three-phase total.

h. Frequency.

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i. THD: Current and voltage.

j. Accumulated Energy: Real kWh, reactive kVARh, apparent kVAh

(signed/absolute).

k. Incremental Energy: Real kWh, reactive kVARh, apparent kVAh

(signed/absolute).

l. Conditional Energy: Real kWh, reactive kVARh, apparent kVAh

(signed/absolute).

2. Power meters shall perform the following demand current calculations, per phase, three-phase average and neutral:

a. Present.

b. Running average.

c. Last completed interval.

d. Peak.

3. Power meters shall perform the following demand real power calculations, three-phase total:

a. Present.

b. Running average.

c. Last completed interval.

d. Predicted.

e. Peak.

f. Coincident with peak kVA demand.

g. Coincident with kVAR demand.

4. Power meters shall perform the following demand reactive power calculations, three-phase total:

a. Present.

b. Running average.

c. Last completed interval.

d. Predicted.

e. Peak.

f. Coincident with peak kVA demand.

g. Coincident with kVAR demand.

5. Power meters shall perform the following demand apparent power calculations, three-phase total:

a. Present.

b. Running average.

c. Last completed interval.

d. Predicted.

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e. Peak.

f. Coincident with peak kVA demand.

g. Coincident with kVAR demand.

6. Power meters shall perform the following average true power factor calculations, demand coincident, three-phase total:

a. Last completed interval.

b. Coincident with kW peak.

c. Coincident with kVAR peak.

d. Coincident with kVA peak.

7. Power Analysis Values:

a. THD, Voltage and Current: Per phase, three phase, and neutral.

b. Displacement Power Factor: Per phase, three phase.

c. Fundamental Voltage, Magnitude and Angle: Per phase.

d. Fundamental Currents, Magnitude and Angle: Per phase.

e. Fundamental Real Power: Per phase, three phase.

f. Fundamental Reactive Power: Per phase.

g. Harmonic Power: Per phase, three phase.

h. Phase rotation.

i Unbalance: Current and voltage.

j. Harmonic Magnitudes and Angles for Current and Voltages: Per phase, up to 31st harmonic.

8. Power meters shall perform one of the following demand calculations, selectable by the User; meters shall be capable of performance of all of the following demand calculations.

a. Block interval with optional subintervals: Adjustable for 1-minute intervals, from 1 to 60 minutes. User-defined parameters for the following block intervals:

1) Sliding block that calculates demand every second, with intervals less than 15 minutes, and every 15 seconds with an interval between 15 and 60 minutes.

2) Fixed block that calculates demand at end of the interval.

3) Rolling block subinterval that calculates demand at end of each subinterval and displays it at end of the interval.

b. Demand calculations initiated by a Utility-furnished synchronization signal:

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1) Signal is a pulse from an external source. Demand period begins with every pulse. Calculation shall be configurable as either a block or rolling block calculation.

2) Signal is a communication signal. Calculation shall be configurable as either a block or rolling block calculation.

3) Demand can be synchronized with clock in the power meter.

c. Minimum and maximum values: Record monthly minimum and maximum values, including date and time of record. For three-phase measurements, identify phase of recorded value. Record the following parameters:

1) Line-to-line voltage.

2) Line-to-neutral voltage.

3) Current per phase.

4) Line-to-line voltage unbalance.

5) Line-to-neutral voltage unbalance.

6) Power factor.

7) Displacement power factor.

8) Total power.

9) Total reactive power.

10)Total apparent power.

11)THD voltage L-L.

12)THD voltage L-N.

13)THD current.

14)Frequency.

d. Harmonic calculation: display and record the following:

1) Harmonic magnitudes and angles for each phase voltage and current through 31st harmonic. Calculate for all three phases, current and voltage, and residual current. Current and voltage information for all phases shall be obtained simultaneously from same cycle.

2) Harmonic magnitude reported as a percentage of the fundamental or as a percentage of rms values, as selected by the VA.

E. Waveform Capture:

1. Capture and store steady-state waveforms of voltage and current channels; initiated manually. Each capture shall be for 3 cycles, 128 data points for each cycle, allowing resolution of harmonics to

31st harmonic of basic 60 Hz.

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2. Capture and store disturbance waveform captures of voltage and current channels, initiated automatically based on an alarm event.

Each capture shall be fully configurable for duration with resolution of at least 128 data points per cycle, for all channels simultaneously. Waveform shall be configurable to capture pre-event cycles for analysis.

3. Store captured waveforms in internal nonvolatile memory; available for PC display, archiving, and analysis.

F. Meter accuracy:

1. Comply with ANSI C12.20, Class 0.5; and IEC 60687, Class 0.5 for revenue meters.

2. Accuracy from Light to Full Rating:

a. Power: Accurate to 0.5 percent of reading.

b. Voltage and Current: Accurate to 0.5 percent of reading.

c. Power Factor: Plus or minus 0.005, from 0.5 leading to 0.5 lagging.

d. Frequency: Plus or minus 0.01 Hz at 45 to 67 Hz.

G. Meter input, sampling, display, output, recording and reading

Capabilities

1. Input: One digital input signal.

a. Normal mode for on/off signal.

b. Demand interval synchronization pulse, accepting a demand synchronization pulse from a utility demand meter.

c. Conditional energy signal to control conditional energy accumulation.

d. GPS time synchronization.

2. Sampling:

a. Current and voltage shall be digitally sampled at a rate high enough to provide accuracy to 63rd harmonic of 60-Hz fundamental.

b. Power monitor shall provide continuous sampling at a rate of 128 samples per cycle on all voltage and current channels in the meter.

3. Display Monitor:

a. Backlighted LCD to display metered data with touch-screen or touch-pad selecting device.

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b. Touch-screen display shall be a minimum 12-inch diagonal, resolution of 800 by 600 RGB pixels, 256 colors; NEMA 250, Type 1 display enclosure.

c. Display four values on one screen at same time.

1) Coordinate list below with meter capabilities specified in subparagraphs above.

2) Current, per phase rms, three-phase average and neutral.

3) Voltage, phase to phase, phase to neutral, and three-phase averages of phase to phase and phase to neutral.

4) Real power, per phase and three-phase total.

5) Reactive power, per phase and three-phase total.

6) Apparent power, per phase and three-phase total.

7) Power factor, per phase and three-phase total.

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.

d. Reset: Allow reset of the following parameters at the display:

1) Peak demand current.

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

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

4. Outputs:

a. Operated either by user command sent via communication link, or set to operate in response to user-defined alarm or event.

b. Closed in either a momentary or latched mode as defined by user.

c. Each output relay used in a momentary contact mode shall have an independent timer that can be set by user.

d. One digital KY pulse to a user-definable increment of energy measurement. Output ratings shall be up to 120-V ac, 300-V dc, 50 mA, and provide 3500-V rms isolation.

e. One relay output module, providing a load voltage range from 20-to 240-V ac or from 20- to 30-V dc, supporting a load current of

2 A.

f. Output Relay Control:

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1) Relay outputs shall operate either by user command sent via communication link or in response to user-defined alarm or event.

2) Normally open and normally closed contacts, field configured to operate as follows:

a) Normal contact closure where contacts change state for as long as signal exists.

b) Latched mode when contacts change state on receipts of a pickup signal; changed state is held until a dropout signal is received.

c) Timed mode when contacts change state on receipt of a pickup signal; changed state is held for a preprogrammed duration.

d) End of power demand interval when relay operates as synchronization pulse for other devices.

e) Energy Pulse Output: Relay pulses quantities used for absolute kWh, absolute kVARh, kVAh, kWh In, kVARh In, kWh

Out, and kVARh Out.

f) Output controlled by multiple alarms using Boolean-type logic.

5. Onboard Data Logging:

a. Store logged data, alarms, events, and waveforms in 2 MB of onboard nonvolatile memory.

b. Stored Data:

1) Billing Log: User configurable; data shall be recorded every

15 minutes, identified by month, day, and 15-minute interval.

Accumulate 24 months of monthly data, 32 days of daily data, and between 2 to 52 days of 15-minute interval data, depending on number of quantities selected.

2) Custom Data Logs: three user-defined log(s) holding up to 96 parameters. Date and time stamp each entry to the second and include the following user definitions:

a) Schedule interval.

b) Event definition.

c) Configured as "fill-and-hold" or "circular, first-in first-out."

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3) Alarm Log: Include time, date, event information, and coincident information for each defined alarm or event.

4) Waveform Log: Store captured waveforms configured as "fill-and-hold" or "circular, first-in first-out."

c. Default values for all logs shall be initially set at factory, with logging to begin on device power up.

6. Alarms.

a. User Options:

1) Define pickup, dropout, and delay.

2) Assign one of four severity levels to make it easier for user to respond to the most important events first.

3) Allow for combining up to four alarms using Boolean-type logic statements for outputting a single alarm.

b. Alarm Events:

1) Over/undercurrent.

2) Over/undervoltage.

3) Current imbalance.

4) Phase loss, current.

5) Phase loss, voltage.

6) Voltage imbalance.

7) Over kW demand.

8) Phase reversal.

9) Digital input off/on.

10)End of incremental energy interval.

11)End of demand interval.

PART 3 - EXECUTION

3.1 INSTALLATION REQUIREMENTS

A. Labeling

1. Labels: Provide labeling in accordance with TIA/EIA-606-A.

Handwritten labeling is unacceptable. Stenciled lettering for all circuits shall be provided using laser printer.

2. Cables: Cables shall be labeled using color labels on both ends with identifiers in accordance with TIA/EIA-606-A.

B. Grounding: ground exposed, non-current-carrying metallic parts of electrical equipment, metallic raceway systems, grounding conductor in metallic and nonmetallic raceways, telecommunications system grounds, and grounding conductor of nonmetallic sheathed cables, as well as

25 10 10 - 25 equipment to eliminate shock hazard and to minimize ground loops, common-mode returns, noise pickup, cross talk, and other impairments.

Comply with VA 27 05 26 GROUNDING AND BONDING FOR COMMUNICATIONS

SYSTEMS and with VA 26 05 26 GROUNDING AND BONDING FOR ELECTRICAL

SYSTEMS.

C. Surge Protection

1. Provide surge protective devices on all metallic cables entering and leaving an interior environment to an exterior environment or vice versa, i.e. surge protective device at each interior location of a penetration to the exterior environment.

D. Network Hardware

1. System components and appurtenances shall be installed in accordance with the manufacturer's instructions and as shown.

2. Future connection to VA network.

H. Electrical Meters

1. Power monitoring and control components shall all be factory installed, wired and tested prior to shipment to the job site.

2. All control power, CT, PT and data communications wire shall be factory wired and harnessed within the equipment enclosure.

3. 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.

4. All wiring required to externally connect separate equipment lineups shall be furnished and installed at the site as part of the contractor’s responsibility.

5. Contractor interconnection wiring requirements shall be clearly identified on the power monitoring and control system shop drawings.

3.2 ADJUSTING AND IDENTIFICATION

A. Install a permanent wire marker on each wire at each termination.

B. Identifying numbers and letters on the wire markers shall correspond to those on the wiring diagrams used for installing the systems.

C. Wire markers shall retain their markings after cleaning.

3.3 FIELD QUALITY CONTROL

A. The power monitoring and control system vendor must be able to provide development, integration and installation services required to complete and turn over a fully functional system including:

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1. Project management to coordinate personnel, information and on-site supervision for the various levels and functions of suppliers required for completion of the project.

2. All technical coordination, installation, integration, and testing of all components.

3. Detailed system design and system drawings.

B. Cabling, equipment and hardware manufacturers shall have a minimum of 5 years experience in the manufacturing, assembly, and factory testing of components which comply with EIA TIA/EIA-568-B.1, EIA TIA/EIA-568-B.2 and EIA TIA/EIA-568-B.3.

3.4 ACCEPTANCE TESTING

A. Develop testing procedures to address all specified functions and components of the Advanced Utility Metering System (AUMS). Testing shall demonstrate proper and anticipated responses to normal and abnormal operating conditions.

1. Provide skilled technicians to start and operate equipment.

2. Coordinate with equipment manufacturers to determine specific requirements to maintain the validity of the warranty.

3. Correct deficiencies and make necessary adjustments to O&M manuals and as-built drawings for issues identified in testing.

4. Provide all tools to start, check-out and functionally test equipment and systems.

5. Correct deficiencies and make necessary adjustments to O&M manuals and as-built drawings for issues identified in any testing

6. Review test procedures, testing and results with Government.

B. Testing checklists: Develop project-specific checklists to document the systems and all components are installed in accordance with the manufacturers recommendation and the Contract Documents.

C. Before testing, the following prerequisite items must be completed.

1. All related equipment has been started and start-up reports and checklists submitted and approved as ready for testing:

2. All associated system functions for all interlocking systems are programmed and operable per contract documents.

3. All punchlist items for the AUMS and equipment are corrected.

4. The test procedures reviewed and approved.

5. Safeties and operating ranges reviewed.

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D. The following testing shall be included:

1. Demonstrate reporting of data and alarm conditions for each point and ensure that alarms are received at the assigned location, including Site Data Collection Device.

2. Demonstrate ability of software program to function for the intended application.

3. Demonstrate via graphed trends to show the reports are executed in correct manner.

4. Demonstrate that the meter readings are accurate using portable NIST traceable portable devices and calibrated valves in the piping system

5. Demonstrate that the systems perform during power loss and resumption of power.

3.5 DEMONSTRATION AND INSTRUCTION

A. Furnish the services of a factory-trained engineer or technician for a total of two four-hour classes to instruct designated Facility

Information Technologies personnel. Instruction shall include cross connection, corrective, and preventive maintenance of the wired network system and connectivity equipment.

B. Before the System can be accepted by the VA, this training must be provided and executed. Training will be scheduled at the convenience of the Facilities Contracting Officer and Chief of Engineering Service.

C. On-site start-up and training of the advanced utility metering system shall include a complete working demonstration of the system with simulation of possible operating conditions that may be encountered.

1. Include any documentation and hands-on exercises necessary to enable electrical and mechanical operations personnel to assume full operating responsibility for the advanced utility monitoring system after completion of the training period.

D. Include 6 days on-site start-up assistance and 3 days on-site training in two sessions separated by minimum 1 month.

E. Regularly schedule and make available factory training for VA staff training on all aspects of advanced utility metering system including:

1. Comprehensive software and hardware setup, configuration, and operation.

2. Advanced monitoring and data reporting.

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3. Advanced power quality and disturbance monitoring.

F. Before the system is accepted by the VA, the contractor shall walk-through the installation with the VA's representative and the design engineer to verify proper installation. The contractor may be requested to open enclosures and terminal compartments to verify cable labeling and/or installation compliance.

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