Updated Book 3.pdf

BOOK THREE OF FOUR

Electrical, Communications Addendum 1: Specification 26 36 23 Added

SPECIFICATION

PROJECT TITLE: EHRM Infrastructure Upgrade Central Western Massachusetts

PROJECT NUMBER: 621-21-700

LOCATION: Edward P. Boland VA Medical Center 421 North Main Street Leeds, MA 01053

PHASE: 100% Construction Documents Submission Addendum 1 Submission

DATE: June 6th, 2023 Addendum 1 Date: June 15th, 2023

621-21-700 - EHRM Infrastructure Upgrades USDVA – Edward P. Boland VA Medical Center

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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’s new Data Center in B22. The metered systems include the electrical power at the main switchboard in the Data Center and shall seamless integrate with the existing Campus System as well as with the new automatic transfer switches at the Data Center. The metering systems will be part of a Campus-Wide utility metering system, rendering the VA accurate and automated metering of its facilities’ energy and equipment status. The existing metering system is comprised of:

1. PC-based workstation and server and software.

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

3. Electric meters, cabinets, current transformers and related components.

4. The proposed new metering at the switchboard and transfer switches shall be seamless integrated into the existing Building Management

System (BMS) Direct Digital Controls. The existing Campus system is a Johnson Controls System.

5. The existing BMS network will be modified, extended and fully integrated with the Advanced Metering System into the existing

Johnson Control System. New network cabling (Cat 6A or fiber) will need to be provided the pathway from the switchboard and transfer switches in B22.

1.2 RELATED WORK

A. Section 13 05 41, SEISMIC RESTRAINT REQUIREMENTS FOR NON-STRUCTURAL

COMPONENTS

B. Section 23 09 23, DIRECT-DIGITAL CONTROL SYSTEM FOR HVAC

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

D. Section 26 05 21, LOW-VOLTAGE ELECTRICAL POWER CONDUCTORS AND CABLES

(600 VOLTS AND BELOW): Low voltage cable.

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E. 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.

F. Section 26 05 33, RACEWAY AND BOXES FOR ELECTRICAL SYSTEMS: Conduits.

G. Section 26 23 00, LOW-VOLTAGE SWITCHGEAR: Secondary distribution switchgear.

H. Section 26 24 13, DISTRIBUTION SWITCHBOARDS: Secondary distribution switchboards.

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.

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

E. 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.

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

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

1024 megabytes.

H. HTML: Hypertext markup language.

I. I/O: Input/output.

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

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

L. LCD: Liquid crystal display.

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

1024 kilobytes.

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

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

P. 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.

Q. 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

R. PC: Personal computer

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

T. 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.

U. 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.

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

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

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

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

1024 gigabytes.

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

BB.THD: Total harmonic distortion.

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

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

EE.WAN: Wide area network.

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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 be integrated into the existing system and 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.

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.

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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.

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 metering devices.

1.7 SUBMITTALS

A. Submit in accordance with specification Section 01 33 23, SHOP DRAWINGS, PRODUCT DATA, and SAMPLES.

B. Product Data: for each type of product indicated, Attach copies of approved Product Data submittals for products (switchboards and switchgear) that describe advance utility metering features to illustrate coordination among related equipment and utility metering and control.

C. 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

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25 10 10 - 6 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. Include a detailed list of all the types of cabinets, meters, CTs etc. being provided including but not limited to: electrical specifications, characteristics, details, mounting arrangements and the proposed location for all equipment including the CT’s needed for the building metering and how it will be integrated into the Advanced

Metering System.

D. 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 print out of graphic screens and related icons, with legend.

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.

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

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F. 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.

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

H. Qualification Data: For installer and manufacturer

I. Other Informational Submittals:

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

J. 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 hardware, cabinet, 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.

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.

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5. Three 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.

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.

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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 from agreed upon completion date.

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 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.

1.11 APPLICABLE PUBLICATIONS

A. Publications listed below (including amendments, addenda, revisions, supplements, and errata) form a part of this specification to the extent referenced, unless otherwise noted. Publications are referenced in the text by the basic designation only.

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B. 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

C. Federal Communications Commission (FCC)

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

D. 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

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

E. International Electrotechnical Commission (IEC)

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

Testing and Measurement Techniques; Surge

Immunity Test

F. National Electrical Contractors Association

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

G. 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

H. National Institute of Standards and Technology (NIST)

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

I. National Fire Protection Association (NFPA)

70-2020.................National Electrical Code (NEC)

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

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

Cables for Use in Air-Handling Spaces

J. 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

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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

K. Underwriters Laboratories, Inc. (UL):

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

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

1.12 WARRANTY

A. Construction Warranty: FAR clause 52.246-21.

PART 2 - PRODUCTS

2.1 ADVANCED UTILITY METERING SYSTEM

A. Functional Description

1. Meter and record load profiles. Chart energy 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 records to allocate energy costs for B22.

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. Emergency Load Shedding (shall be made available but not programmed unless indicated by the COR that one or more systems

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25 10 10 - 13 shall be included). Preserve critical loads or avoid total shutdown due to unforeseen loss of power sources according to the following logic:

1) Determine system topology.

2) Evaluate remaining loads and sources.

3) Shed loads in less than 100 ms.

f. Demand Management (shall be made available but not programmed unless indicated by the COR that one or more systems shall be included):

1) Peaking or co-generator control.

2) Load interlocking.

3) Load shedding.

4) Load trimming.

g. System: Refer to Section 23 09 23 for additional details. Report equipment status and power system control. This campus has standardized on an existing standard ASHRAE standard 135, BACnet/IP Control System supported by a preselected controls service company. This entity is referred to as the “Control

System Integrator” in this Section of the technical specifications. The Control system integrator is responsible for system graphics and expansion. It also prescribes control system-specific verification procedures to the contractor administered by this Section of the technical specification. It lastly provides limited assistance to the contractor administered by this Section of the technical specification in its commissioning/verification work.

2. The Contractor of this project shall directly hire the Control

System Integrator in a contract separate from the contract procuring the controls contractor administered by this Section of the technical specifications.

3. The contractor administered by this Section of the technical specifications shall coordinate all work with the Control System

Integrator. The contractor administered by this Section of the technical specifications shall integrate the ASHRAE Standard 135, BACnet/IP control network(s) with the Control System Integrator’s area control through an Ethernet connection provided by the Control

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System Integrator. Coordinate with the electrical contractor for a data jack adjacent to the ECC location.

4. The contractor administered by this Section of the technical specifications shall provide a peer-to-peer networked, stand-alone, distributed metering system. This direct digital control (DDC) system shall include one portable operator terminal - laptop, one digital display unit, microprocessor-based controllers, instrumentation, end control devices, wiring, software, and related systems. This contractor is responsible for all device mounting and wiring.

5. Responsibility Table: The General Contractor shall be responsible for coordination between the appropriate sub-contractors, the control system integrator, and the VA.

Item/Task Section 23 09 23 contractor

Control system integrator

VA

ECC expansion X ECC programming X Devices, meters, CT’s, control panels and equipment

X

Point addressing: all hardware and software points including setpoint, calculated point, data point(analog/ binary), and reset schedule point

X

Point mapping X Network Programming X ECC Graphics X Metering programming and sequences

X

Integrity of LAN communications

X

Electrical wiring X Operator system training X LAN connections to devices X LAN connections to ECC X IP addresses X Overall system verification X Controller and LAN system verification

X

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

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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.

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) 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

2.2 CABLE SYSTEMS - TWISTED PAIR AND FIBER OPTIC

A. General:

1. All metallic cable sheaths, etc. (i.e.: risers, underground, station wiring, etc. shall be grounded.

2. Install temporary cable and wire pairs so as to not present a pedestrian safety hazard. Provide for all associated work for any temporary installation and for removal when no longer necessary.

Temporary cable installations are not required to meet Industry

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Standards; but, must be reviewed and approved by the VA prior to installation.

3. Cable conductors to provide protection against induction in circuits. Crosstalk attenuation within the System shall be in excess of -80 dB throughout the frequency ranges specified.

4. Minimize the radiation of RF noise generated by the System equipment so as not to interfere with audio, video, data, computer main distribution frame (MDF), telephone customer service unit (CSU), and electronic private branch exchange (EPBX) equipment the System may service.

5. The as-installed drawings shall identify each cable as labeled, used cable, and bad cable pairs.

6. Label system’s cables on each end. Test and certify cables in writing to the VA before conducting proof-of-performance testing.

Minimum cable test requirements are for impedance compliance, inductance, capacitance, signal level compliance, opens, shorts, cross talk, noise, and distortion, and split pairs on all cables in the frequency ranges specified. The cable tests shall demonstrate the operation of this cable at not less than 10 mega (m) Hertz (Hz) full bandwidth, fully channel loaded and a Bit Error Rate of a minimum of 10-6 at the maximum rate of speed. Make available all cable installation and test records at acceptance testing by the VA and shall thereafter be maintained in the Facility’s Telephone

Switch Room. All changes (used pair, failed pair, etc.) shall be posted in these records as the change occurs.

8. Provide all cable pairs/circuits from the Server Room and establish circuits throughout the Facility for all cabling as described herein.

9. Provide proper test equipment to demonstrate that cable pairs meet each OEM’s standard transmission requirements, and guarantee the cable will carry data transmissions at the required speeds, frequencies, and fully loaded bandwidth.

B. LAN COPPER CABLES

1. Comply with Section 27 10 00 "Structured Cabling."

2. RS-485 Cable:

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a. PVC-Jacketed, RS-485 Cable: Paired, 2 pairs, twisted, No. 22 AWG, stranded (7x30) tinned copper conductors, PVC insulation, unshielded, PVC jacket, and NFPA 70, Type CMG.

3. Unshielded Twisted Pair Cables: Category 6A.

4. Cabling products shall be tested and certified for use at data speeds up to at least 100 Mbps. Other types of media commonly used within IEEE Std 802.3 LANs (e.g., 10Base-T and 10Base-2) shall be used only in cases to interconnect with existing media. Short lengths of media and transceivers may be used in these applications.

Provide separately orderable media, taps and connectors.

5. Ethernet Switch shall be IEEE Std 802.3 bridges which shall function as the center of a distributed-star architecture and shall be

"learning" bridges with spanning tree algorithms in accordance with

IEEE Std 802.1D. The switch shall support the connected media types and shall have a minimum of 150% the required ports and no fewer than 4 ports. One port shall be switch selectable as an uplink port.

6. Provide IP router network equipment. The routers shall be fully configurable for protocol types, security, and routing selection of sub-networks. The router shall meet all requirements of RFC 1812.

C. LAN FIBER OPTICAL CABLES

1. Interior Fiber Optic Cable: Interior Fiber Optic Cable shall be

Multimode or Singlemode fiber, 62.5/125 micron for multimode or

10/125 micron for singlemode micron with SC or ST connectors as specified in TIA-568-C.1. Terminations, patch panels, and other hardware shall be compatible with the specified fiber and shall be as specified in Section 27 10 00 " Structured Cabling." The data communications equipment shall use the 850-nm range of multimode or

1310-nm range of singlemode fiber-optic cable. Fiber-optic cable shall be suitable for use with the 100Base-FX standard as defined in

IEEE Std 802.3.

2. Exterior Fiber Optic Cable: Exterior Fiber Optic Cable shall be

Multimode or Singlemode Fiber, 62.5/125 micron for multimode or

10/125 micron for singlemode micron with SC or ST connectors as specified in TIA-568-C.1. Terminations, patch panels, and other hardware shall be compatible with the specified fiber and shall be as specified in Section 27 10 00 "Structured Cabling.". The data communications equipment shall use the 850-nm range of multimode or

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1310-nm range of singlemode fiber-optic cable. Fiber-optic cable shall be suitable for use with the 100Base-FX standard as defined in

IEEE Std 802.3.

3. Fiber Optic Patch Panels shall be wall or rack mountable and designed to provide termination facilities for up to 24 fibers. Unit shall also have capability to be equipped with spliced trays, six packs (for adapters), and blank panels for easy termination of the fiber bundles and tube cables. Fiber-optic terminating equipment shall provide for mounting of ST or SC connectors on an optical patch panel. Provide fiber-cable management and cable-routing hardware to assure conformance to minimum fiber and cable bend radii. Connectors on the patch panel shall be ST or SC feed through.

Provide access to both sides of the panel. The patch panel for the connectors shall be mounted to facilitate rearrangement and identification. Each apparatus shall have cabling and connection instructions associated with it.

4. Fiber Optic media converter shall provide media conversion between layer 1 copper and fiber media to support data rates equal to the greater of the physical layer or 100 Mbps as specified in IEEE Std

802.3.

D. LOW-VOLTAGE WIRING

1. Low-Voltage Control Cable: Multiple conductor, color-coded, No. 20 AWG copper, minimum.

a. Sheath: PVC; except in plenum-type spaces, use sheath listed for plenums.

b. Ordinary Switching Circuits: Three conductors, unless otherwise indicated.

c. Switching Circuits with Pilot Lights or Locator Feature: Five conductors, unless otherwise indicated.

2.3 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.

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2.4 METER COMMUNICATION

A. Integrate with the existing BACnet system to allow communications from the meter to the (BMS) building management system.

2.5 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 100-2500 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.

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 1 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 or from a fused secondary source directly

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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 100-30

5. CT’s shall be provided in conjunction with the metering system. CT’s shall be rated for metering class either solid core or split core with an accuracy class of Class 1.

6. Include shorting type terminal blocks for all CT leads located as approved by the COR.

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.

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:

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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.

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.

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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:

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.

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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.

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.

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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.

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.

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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:

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.

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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."

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.

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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. Cabling

1. Install Category 6A UTP, and optical fiber cabling system as detailed in TIA-568-C.1, TIA/EIA-568-B.2, or TIA-568-C.3.

2. Screw terminals shall not be used except where specifically indicated on plans.

3. Use an approved insulation displacement connection (IDC) tool kit for copper cable terminations.

4. Do not untwist Category 6A UTP cables more than 12 mm (1/2 inch) from the point of termination to maintain cable geometry.

5. Provide service loop on each end of the cable, 3 m (10 feet) at the server rack and 304 mm (12 inches) at the meter.

6. Do not exceed manufacturers' cable pull tensions for copper and optical fiber cables.

7. Provide a device to monitor cable pull tensions. Do not exceed 110

N (25 pounds) pull tension for four pair copper cables.

8. Do not chafe or damage outer jacket materials.

9. Use only lubricants approved by cable manufacturer.

10.Do not over cinch cables, or crush cables with staples.

11.For UTP cable, bend radii shall not be less than four times the cable diameter.

12.Cables shall be terminated; no cable shall contain unterminated elements.

13.Cables shall not be spliced.

14.Label cabling in accordance with paragraph Labeling in this section.

B. 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.

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C. Grounding: ground exposed, non-current-carrying metallic parts of electrical equipment, metallic raceway systems, grounding conductor in metallic and nonmetallic raceways,…