Attachment__2_26-27-13.PDF

SECTION: 26 27 13.10 30 ELECTRIC METERS

Criteria

a. Quality Assurance: EP415-1-261, Volume 4

b. UFGS SECTION 26 20 00 INTERIOR DISTRIBUTION SYSTEM

c. THE IESNA LIGHTING HANDBOOK

d. NFPA 101 Life Safety Code

e. NFPA 70 National Electrical Code

f. IEEE C2 National Electric Safety Code

g. UFC 3-520-01 INTERIOR ELECTRICAL SYSTEMS

h. Federal Sustainable Acquisition Items/Requirements

i. Resource Conservation and Recovery Act (RCRA) , Section 6002

j. Executive Order 13693

k. DoD Green Procurement Policy (Aug 27 2004)

l. DoD Green Procurement Strategy (Nov 2008)

m. Army Green Procurement Policy (Nov 22 2006)

n. Federal Acquisition Regulation, Part 23.4

o. Federal Acquisition Regulation, Subpart 36.601-3

p. EPA Comprehensive Procurement Guidelines

q. EPA Guidance on Environmentally Preferable Purchasing

r. HJB Form 225 (JBLM Sustainable Acquisition Exception Form)

s. UFC 1-200-02 High Performance and Sustainable Building Requirements

t. ASA IE&E Sustainable Design and Development Policy (Dec 16 2013)

Changes or Criteria Notes to Unified Facilities Guide Specifications (UFGS) Paragraph # and Title (if any) Note to Designer Change Text

1.3 SUBMITTALS Delete reference to Section 01 33 29, unless incorporated into the contract specs.

Design Requirements a.

Purpose:

a. The purpose of the following specification is to achieve meter equipment compatibility with the Army Metering Program pursuant to Public Law 109-58, Section 103 of the Energy Policy Act of 2005. This does not replace the Unified Facility Guide Specifications on metering; additional technical and installation requirements and applicable references may be located there as needed. This specification provides guidance to meet the minimum requirements for metering as established by public law and Army policy. The intent is for all advanced meters to report their data to an installation-centric energy reporting and management system such as a Utility Monitoring and Control System or Advanced Metering Data Management System (MDMS) Installation Level front end. This approach is consistent with UFC 3-400-01, Energy Conservation. Paragraph 2-5, Meters, states: “All meters shall be connected to a base wide energy and utility monitoring and control system either directly or via the building HVAC control system.” The advanced meters must provide data at least daily and measure at least hourly consumption of electricity in fifteen minute intervals.

b. General Theory of Operation: Utility Meters are installed to monitor electricity, gas, water, and steam usage. These meters are connected to a Field Control Network - via Modbus RTU over RS 485. They communicate over this field control network to a device which connects the field control network to an internet protocol (IP) network, and then over this IP network to an "Installation Level Front End", in this case the Enterprise Energy Data Reporting System (EEDRS). At the EEDRS the information from the meter is provided to the graphical user interface (and other functionality) that is part of the UMCS for use by installation personnel (such as DPW and energy managers) and is also logged and stored in a Structured Query Language (SQL) database. This SQL database may be the database regularly used by the EEDRS or a separate SQL database installed specifically for this purpose. On a regular basis the MDMS Gateway, located in the DMZ of the installation (outside the inner firewall) retrieves data from the SQL database and sends it to the MDMS Server.

Notes:

1) In some cases electric meters may be connected directly to an IP network, but this is considered a non-standard approach. (THIS

METHOD WILL NOT BE USED AT JBLM)

2) The approach detailed above is used for other (non-electrical) metering also, but generally only total consumption is measured for non-electricity meters, and non-electricity meters may provide a pulse output that is measured by a controller on the network in lieu of being connected to the network themselves.

c. The means for meter data transmission using open-protocols such as ANSI/CEA 709.1b and Modbus RTU over Government owned transport media (LAN, wireless, radio.) will be site specific and subject to the approval of the Network Enterprise Center (NEC). These specifications provide the flexibility needed to support the various data transmission system alternatives in addition to meeting the minimum standards for energy consumption data recording and reporting. A key element for success will be integrating these systems with the Army’s Information Technology (IT) networks supported by Network Enterprise Centers (NEC).

12/22/2016http://www.lewis-mcchord.army.mil/designstandards/DIVISION%2026%20-%20ELECT...

Applicability: These requirements apply to all Army meters for use on facilities that meet the size and energy-consumption selection criteria regardless of the funding source and method of procurement (i.e. Military Construction Army (MCA) projects, Utility Privatization contracts, Energy Savings and Performance Contracts, or Sustainment Modernization and Repair projects).

Definitions:

a. Advanced Metering Data Management System Installation Level front end. This term as used in the specification refers to the system that will collect, manage, and display the meter data for the local energy manager. At JBLM this shall be the Enterprise Energy Data Reporting System (EEDRS). The intent of the Army Metering Program is to provide the metering data to the local engineering staff first within the building automation system that can execute application programs to affect savings, and then transmit to the Enterprise Meter Data Management System, when activated.

b. Advanced Meters. For this specification, Advanced Meters are those that have the capability to measure and record interval data (at least hourly for electricity), and communicate the data to a remote location in a format that can be easily integrated into an advanced meter data management system. Most advanced meters offer additional features which may be attractive to system owners.

References:

a. UFGS 26 27 13.10 30, ELECTRIC METERS prepared by the Air Force

b. UFGS 26 27 14.00 20, ELECTRICITY METERING prepared by the Navy

Although these are listed as Unified in the Construction Criteria Base the preparing activity has focused on their specific requirements that may not fulfill the Army’s needs. However, as this Mandatory Center of Expertise (MCX) guidance is not intended to provide the level of detail for contract requirements, the designer should refer to these as needed and include the detail for completeness. The Navy specification has some excellent drawings/sketches that are useful. The goal is to create a truly unified Metering Specification in

FY13.

c. Additional documentation required and available as separate electronic media files at:

http://www.hnd.usace.army.mil/umcs/umcs_resources.aspx

1. Enterprise Energy Data Reporting System Security Functional Architecture Ver3.4.doc (Paragraph 2.1.a)

2. Advanced Meter Points List.xls (paragraph 3.3.2)

3. I3A Technical Criteria Feb 2010.pdf (paragraph 2.3.a)

GENERAL OUTLINE

1. Installation Level Front End Computer

2. MODBUS/ BACnet Open Protocol

3. Meter Data Schema

4. Meter Identification and Location Data

5. Storage of Metered Data

6. Workstation Display

7. Energy Reports

8. Communications

9. Between Meters and Installation Level Front End

10. Between Installation Level Front End and Enterprise MDMS System

11. Information Assurance Requirements

12. Meters

13. Environmental Tolerances of Metering Devices

14. Smart Meter Capability

15. Communication Protocol and Methods

16. Pulse Input Data Port Interface

17. Data Storage and Trend Logs

18. Meter Display

19. Electric Meter

20. Requirements

21. Mandatory Measured Variables

22. Accuracy

23. Surge Protection

24. Instrumentation (CTs and PTs)

25. Disconnects and Shorting Blocks

26. Gas Meter

27. Requirements

28. Gas Meter Types

29. Valves and Regulators

30. Gas Meter Installation

31. Connections

32. Pressure and Leak Tests

33. Water Meter

34. Requirements

35. Water Meter Types

36. Water Meter Installation

37. Valves

38. Connections

39. Disinfection

40. Tests and Inspections

41. Steam Meter

42. Requirements

43. Steam Meter Types

44. Steam Meter Installation

45. Piping Tests

4.0 Execution

5.0 Training

1.0 INSTALLATION LEVEL FRONT END COMPUTER

1.1 MODBUS Open Protocol. The design shall include a MODBUS Based Open System Host for the front end data management system. The MODBUS Based Open System Host shall be installed in accordance with Specification UFGS 25 10 10 Utility Monitoring and Control System (UMCS) Front End. The MODBUS Based EEDRS System Host requires building TP/FT-10 data communication infrastructure for meter connectivity. UFGS 23 09 23 provides guidance on the communication media.

1.2 Meter Data Schema. The metering data shall be stored per the defined schema and set in a full version Microsoft SQL data base for future retrieval by others to a site Meter Data Management System (MDMS) Gateway that will report to an Enterprise Army Meter Data Management System. The Microsoft SQL data base may be an entirely separate SQL data base dedicated to meter data only or native to the Host EEDRS/Metering Front end.

a. Define in the following format: /BLCx/Buildingy_Meterz_point_15

Where:

BLC is the building level controller used. It may be a Java Application Control Engine (JACE) or a Network Automation Engine (NAE) or a router or other.

x is the building number containing the BLC y is the building number containing the meter z is the meter number within the building point is the name of the measured variable:

KW for electrical demand/power KWH for electrical energy PF_AVG for power factor PULSE_aaa for a consumption meter, aaa refers to the input designation. Contractor shall provide the necessary point name mapping and conversion information.

Others as required

The _15 indicates that these values came from 15 minute history data.

Note also that the building level controller name, /JACEx/, may be automatically pre-pended by EEDRS host. The future Meter Data Management System (MDMS) Gateway will repackage the required data into a Comma Separated Value (CSV) file form for transmission to the MDMS Enterprise Server.

b. Provide the following meter data:

a.

PWR-TOT Real Power (Total) KW KWH-TOT Total KWH (Total Energy) KWH PWR-DEMAND-PEAK Historical Peak Demand Power KW PWR-DEMAND Demand Power KW VOLT-A Rms Voltage For Phase A VOLTS VOLT-B Rms Voltage For Phase B VOLTS VOLT-C Rms Voltage For Phase C VOLTS AMP-A Rms Current For Phase A AMPS AMP-B Rms Current For Phase B AMPS AMP-C Rms Current For Phase C AMPS HZ-AVG Average Line Frequency HZ PF-AVG Average Power Factor N/A b.

1.3 Meter Identification and Location Data. Contractor shall populate the sample information document shown in the table below and display and store at Installation Level Front End Computer.

c.

Fort Sample Electric Meter Information

Bldg No. Bldg Name Bldg Sqft Category

Meter Name Commodity Type

Area served by meter

(sqft) Reimbursable (Y/N)Code 71 EXCH MAIN STORE 74,053 74053 0001E00071EMON Electricity 74,053 y 01440 HAAF HEALTH CLINIC 49,679 55010 0033E1440HEMON Electricity 49,679 N 2905 OPEN STR INST 40,264 45210 0034E02905EMON Electricity 40,264 N 4541 VEH MAINT SHOP 32,648 21410 0035E04541EMON Electricity 32,648 N 06007 HAAF ARMY LODGING 43,732 72010 0038E6007HEMON Electricity 43,732 N 7560 DEPENDENT SCH 31,040 73046 0043E07560EMON Electricity 31,040 y 7742 CO HQ BLDG 30,000 14185 0044E07742EMON Electricity 30,000 N 10501 CSMS/MATES 31,093 21419 0045E10501EMON Electricity 31,093 y 10531 CSMS/MATES 34,843 21419 0046E10531EMON Electricity 34,843 Y d.

1.4 Storage of Metered Data. The Enterprise Energy Data Reporting System Installation Level Front End, shall store all required meter data for a minimum of two years.

1.5 Workstation Display

a. System shall display all mandatory metering data (electricity, water, gas and steam) upon request in an organized and easily readable format. Data shall be displayed in no less than 15 minutes intervals.

b. Final install of front end equipment shall, at minimum, display accurate data readings for each meter in a text format.

Display capability shall include multiple graphical formats such as data vs. time (minutes, hours, days, weeks, months, and year) comparison between metered data from two or more meters and other standard meter data. Site specific graphics shall be created that display the required metered value, meter location, meter serial number and building square footage served by that meter. In addition, contractor shall differentiate by an asterisk on the graphic display those meters that were not installed by the Army Metering Program.

c. Contractor shall provide two hardcopies and two copies on electronic media (DVD or CD) of detailed instructions for customization and integration of additional display features that are not prepared at the time of final install.

1.6 Energy Reports. The Installation Level Front End Computer shall be configured to provide monthly energy reports that show:

a. Specific building kWh and max kW use and time and day the max occurred.

b. A building’s monthly kWh and max monthly kW with history over the previous 24 months. Include Heating Degree-Days (HDD) and Cooling Degree-Days (CDD) for each month.

c. Summary of what all buildings are using on an installation relative to their square footage (energy consumption density) as a function of kWh and kW peak; when meters are available include the Natural Gas (NG) and water usage including their maximum rate of use for that month. Include HHD and CDD.

d. A bar chart showing the 24 month history of what the installation is using total (kWh, KW peak, NG, and water) and the energy density based on square footage of metered buildings. Include HDD and CDD for each month.

e. A bar chart showing dollar cost for the commodities from the chart above over a 24 month period. Include HDD and CDD for each month.

f. A dirty dozen list of the buildings using the highest energy based on square footage, occupancy rates, hours of use, and a factor coefficient to decrease the rating for high energy density demand type missions. This mission coefficient shall be the same for the same type of mission and applied the same on every installation.

2.0 COMMUNICATIONS

2.1 Between Meters and Installation Level Front End

a. The communications medium shall be compatible with the Installation Level Front End Computer and the Enterprise Energy Reporting Data System (EERDS) Security Functional Architecture available as separate electronic media: Enterprise Energy Data Reporting System Security Functional Architecture.doc. The installation of wire, fiber optic cable, wireless network equipment, network switches, and media converters is required where existing communications infrastructure is non-existent to support communications between the buildings to be metered and the nearest base network access point. If fiber optic cable is required, coordinate with the site NEC for installation guidance and sizing (25 pair is preferred). All IP, Ethernet, or wireless communication design and implementation plans shall be approved by the site NEC.

b. Radio Frequency (RF) transceivers shall be DoD/NETCOM approved and have an existing J/F (joint format)12 number.

This is the identification number assigned to a system after the Application for Equipment Frequency Allocation (DD form 1494) is approved, for example, J/F 12/6309 (sometimes called the J-12 number).Contractor shall be responsible for obtaining installation Frequency Manager/Officer and host nation approval.

c. Coordinate with the Activity and provide specific requirements "to match existing systems" when necessary. Contractor shall verify that the electricity meter installed on any building site is compatible with the post-wide metering system with respect to the types of meters selected and the method used to program the meters for initial use. Software and meter programming tools are necessary to setup the meters described by this specification. New software tools different from the meter programming methods currently used by post personnel shall require separate approval for use. Contractor shall verify that the metering system installed on any building site is compatible with the facility-wide or post-wide communication and meter reading protocol system.

2.2 Between Installation Level Front End and Enterprise MDMS System

See Paragraph 1.2. The MDMS Contractor shall execute a retrieval of the data in the Microsoft SQL data base. The MDMS Contractor shall format the meter data to include the site specific information that uniquely indentifies the installation (Fort Carson, Fort Hood, etc.). IPSec tunneling may be used to securely transport data. There will likely be a gateway between the Installation Level Front End Computer and the Enterprise MDMS.

2.3 Information Assurance Requirements

a. The process and related requirements to attain certification and accreditation for metering systems are under revision. Any standard procedure issued as part of this specification will likely need modification soon. The DoD Information Assurance guidance (DoDI 8500 series) and UFGS 25 10 10, Utility Monitoring and Control System are being rewritten and have major revisions that affect communication protocol and security engineering. Once those changes get published and implemented, some standard procedures can be set. However, authoritative guidance does exist to shape architectural templates and influence the design process for the Installation Information Infrastructure Architecture (I3A) for Army installations. This document is Technical Criteria for the Installation Information Infrastructure Architecture and is available at the website noted in References, paragraph c.

b. The Information Assurance and Security Engineering Directorate (IASED) in Fort Huachuca, AZ, is conducting testing and hardening for a limited number of metering host configurations that may assist in final IA certification and accreditation documents.

As the documentation is created for individual systems there exist opportunities to leverage this knowledge to engineer a metering system that will more easily be approved by the NEC.

c. Networthiness: The contractor shall provide and prepare documentation as required by AR 25-1 and submit a request for a Certificate of Networthiness (CoN). Networthiness certification is required before connecting hardware/software to the Army Enterprise Network. The selection of system components from the Defense Information Systems Agency (DISA) Approved Products List is required, when available. There is also a list of preapproved software that identifies those that have CoNs. The Contractor shall coordinate all Networthiness efforts with the appropriate installation NEC as well as higher NETCOM headquarters. When issued and certified, the Contractor shall comply with the applicable IATO (Interim Authority to Operate) configuration stand-up guide.

d. In the eyes of a security engineer, IP meters have been regarded as vulnerable and assumed to create a higher risk to the defense in depth architecture. This unfortunately denies the use of a powerful device that has the advantage of web based services and time stamps. The IP meter interface also offers a more robust transfer of data and the ability to remotely reset counters. This risk assessment is subject to change as testing is completed.

e. While in the design and planning stage, contact the UMCS-MCX for the most recent update on metering system configurations and their affect on information assurance.

3.0 METERS

Note: Reimbursable facilities/customers that require metering devices which exceed the requirements detailed in this specification shall be installed per written request as approved and provided in pre-proposal documentation.

3.1 Environmental Tolerances of Metering Devices

a. Power Meters:

(1) Outdoor/exterior devices shall be rated for operation and storage from minus 40 degrees C to plus 70 degrees C or better and 5 to 100% relative humidity (RH) (non-condensing). Exterior meters shall be provided with or installed within a NEMA 4 enclosure. Enclosures shall be NEMA 4X for coastal and corrosive environments. When ambient temperature extremes exceed the rating above, provide enclosures with heat strips to maintain operable temperatures. Enclosures shall be lockable (key lock) for information security issues.

(2) Indoor/interior devices shall be rated for operation and storage from 0 degrees C to plus 50 degrees C or better and 5 to 90% relative humidity (non-condensing). Interior meters or meters located in mechanical rooms shall be provided with or installed within a NEMA 12 lockable enclosure.

b. Water Meter Operating Temperatures: 0 degrees C to plus 50 degrees C or better. Water Meter Humidity Operating Range: 5% to 90% RH (non-condensing).

When above frost line and exterior mounting is required, consider the local ambient temperature extremes and protect from freezing with insulated, moisture proof enclosures and heat tracing as required.

c. Gas Meter Operating Temperatures: minus 40 degrees C to plus 70 degrees C.

Gas Meter Humidity Operating Range: 5% to 90% RH (non-condensing).

d. Steam Meter Ambient Operating Temperatures: minus 40 degrees C to plus 80 degrees C. Steam Meter Medium Operating Temperatures: minus 40 degrees C to plus 240 degrees C.

Humidity Operating Range: 5% to 90% RH (non-condensing)

e. All interior meters and/or remote interface displays shall be provided with or installed within a NEMA 12 enclosure.

3.2 Smart Meter Capability

a. All meters as installed shall provide smart meter capabilities, either as a single product, or as installed in conjunction and collocated with another product such that the combined installation provides smart meter capabilities.

b. Meters that do not provide factory smart capabilities shall provide a pulse output for interfacing to a smart meter. The minimum and maximum pulse rate and pulse width of the receiving digital input device and software, i.e., electric meter, digital input card on the UMCS or any other accumulator shall be determined by the contractor. The contractor shall provide pulse rate convertors if required. Depending on the product used, relay isolation may be required when connecting to the Input/Output (I/O) device. In addition, the contractor shall determine and eliminate false triggers caused by distance or routing near other voltage sources. It is strongly advised to adhere to the manufacturers’ recommendations and industry practices and install isolation relays as field conditions dictate.

3.2.1 Communication Protocol and Methods. Meters shall communicate via Modbus RTU, protocol to the existing Enterprise Energy Data Reporting System Installation Level Front End (EEDRS).

3.2.2 Pulse Input Data Port Interface

a. Meters shall have a data port connection compatible with the selected protocol which communicates to the existing Enterprise Energy Data Reporting System Installation Level front end. The meter’s interface must be compatible with the conditions at any given site. Analog current loops shall not be used.

b. Auxiliary data ports. Unless otherwise specified, smart meters shall have a minimum of two pulse inputs for incorporation of other external meter data.

3.2.3 Data Storage and Trend Logs

a. Unless otherwise specified, the meter must be capable of providing and storing 15 minute interval data for 20 distinct points for minimum of 30 days to non-volatile memory. The measured energy consumption shall be retained in non-volatile memory. The maximum demand and time of maximum demand shall be stored in non-volatile memory and can be reset.

b. Field Interface Tool: Contractor shall provide a field interface tool with the compatible software to extract stored trend data and logs from meters. This is a separate hand-carried device that directly connects with the meter at the installed site.

3.2.4 Meter display. Meters that are required to display data shall provide face plate configurable menus to select the desired data for display. Display requirements may be met with the installation of a local display panel connected to the meter. All collected data shall be capable of display.

3.3 Electric Meter

3.3.1 Requirements

a. The meters must comply with the applicable requirements of American Society of Heating, Refrigerating and Air- Conditioning Engineers (ASHRAE) 189.1. Where conflicts occur between this guidance and the ASHRAE standard, ASHRAE 189.1 shall prevail.

b. Power Systems: Meters shall be designed for multifunction electrical measurement on either single or 3 phase power systems. Meter shall support the power configuration as identified at site specific government facilities: single phase (120 or 240 volt);

3 Phase, 3 Wire Delta; 3 Phase, 4 Wire Delta; 3 Phase, 4 Wire Wye (2.5 Element); 3 Phase, 4 Wire Wye (3.0 Element). For three phase application voltage range is 208 – 600V. All meters shall be UL 508 Listed, CSA approved, have CE marking, and meet safety standards UL 1244 or UL 1010-1.

3.3.2 Mandatory measured variables: See Electric Meter points list: Advanced Meter Points List.xls for details and additional requirements. Points list assumes a 4 wire delta power configuration. Modify to match site specific requirements.

e.

PWR-TOT Real Power (Total) KWH-TOT Total KWH (Total Energy) PWR-DEMAND-PEAK Historical Peak Demand Power PWR-DEMAND Demand Power VOLT-A Rms Voltage For Phase A VOLT-B Rms Voltage For Phase B VOLT-C Rms Voltage For Phase C AMP-A Rms Current For Phase A AMP-B Rms Current For Phase B AMP-C Rms Current For Phase C HZ-AVG Average Line Frequency PF-AVG Average Power Factor f.

Optional Measured values:

g.

PWR-A Real Power For Phase A PWR-B Real Power For Phase B PWR-C Real Power For Phase C HZ-A Frequency For Phase A HZ-B Frequency For Phase B HZ-C Frequency For Phase C KVA-TOT Total Kva KVA-A Kva For Phase A KVA-B Kva For Phase B KVA-C Kva For Phase C KVAR-TOT Total Reactive Power KVAR-A Reactive Power For Phase A KVAR-B Reactive Power For Phase B KVAR-C Reactive Power For Phase C KVARH-TOT Total Kvarh (Total Reactive Energy) KVARH-A Kvarh (Total Reactive Energy) For Phase A KVARH-B Kvarh (Total Reactive Energy) For Phase B KVARH-C Kvarh (Total Reactive Energy) For Phase C PF-A Power Factor For Phase A PF-B Power Factor For Phase B PF-C Power Factor For Phase C h.

3.3.3 Accuracy

a. System Accuracy: System accuracy for the meter product devices including instrument transformers shall not exceed plus or minus 1.5% as calculated using the Root Sum Square (RSS) method and assuming normal distribution.

b. Meter Accuracy: Meter certification shall be IEEE/ANSI C12.20, Accuracy class 0.5% or the meter shall be calibrated with National Institute of Standards and Technology (NIST) traceable standards to an accuracy of 0.5% or better.

c. For reimbursable tenants meter certification shall be NEMA/ANSI C12.20, Accuracy class 0.2%. These meters shall include a Meter display that can display all recorded values.

3.3.4 Surge Protection: Meters shall comply with IEEE/ANSI C37.90.1, Standard surge withstand capability (SWC) tests for relays and relay systems associated with electric power apparatus and IEEE C62.41.

3.3.5 Instrumentation (CTs and PTs)

a. Current transformers (CTs) sized properly so that the meter secondary of the transformer shall output current to ensure at least a plus or minus 0.6% accuracy of current when measured between 10% and 90% of full amperage range.

b. CTs shall not exceed 5 amps on the secondary side.

c. Burden on CTs shall not exceed rated burden for the accuracy class.

d. CTs shall be provided in solid or split core configurations.

e. CTs shall be provided in the appropriate ranges to meet the service entrance amperage requirements.

f. CTs shall be revenue grade and certified per IEEE/ANSI C57.13 or IEC 185.

g. CTs shall be provided that are rated for the appropriate matching frequency of the power generation (60 Hertz CONUS and 50 Hertz OCONUS where applicable).

h. Current sensors shall be sized properly for the application and provide a voltage (normally 0-2 volts) to the meter that results in at least a plus or minus 0.6% accuracy of current when measured between 10% and 90% of full amperage range.

i. Voltage or Potential Transformers (PTs) sized properly so that the meter secondary of the transformer shall output voltage to ensure at least a plus or minus 0.6% accuracy of voltage when measured from zero to the IEEE/ANSI C57.13 or IEC 185 specified standard burden, at the specified standard burden power factor, and at any value from 90% to 110% of rated voltage.

j. PTs shall be revenue grade and certified per IEEE/ANSI C57.13 or IEC 185.

k. Burden on PTs shall not exceed rated burden for accuracy class.

3.3.6 Disconnects and Shorting Blocks

a. The appropriate metering accessories, terminal blocks, shorting blocks, and fuses shall be built into each enclosure and the enclosure shall have an appropriate grounding termination point per standard industry practices. Disconnect wiring blocks shall be provided between the current transformer and the meter where 5 AMP current transformers are used. A shorting mechanism shall be built into the wiring block to allow the current transformer wiring to be changed between shorting block and meter without removing power to the transformer. The wiring blocks shall be located where they are accessible without the necessity of disconnecting power to the transformer. For multi-ratio current transformers, provide a shorting block from each tap to the common lead. The shorting mechanism must be capable of carrying the current of each current transformer so that the electric meter can be safely removed from the circuit for testing or repair. Low voltage, 0-5 volt current sensors are exempt from the shorting block requirement.

b. Voltage-monitoring circuits shall be equipped with disconnect switches to isolate the meter base or socket from the voltage source.

c. Short circuit protection for each power supply circuit or measuring voltage circuit entering the enclosure must be included in the enclosure. This shall be appropriately sized to protect equipment and personnel should an accidental short occur during maintenance inside the enclosure. Fuses or breakers with appropriate UL ratings shall be used. Fuse type and rating shall be depicted on the As-Built drawings.

d. Switching mechanisms adequate to de-energize all power supply and voltage circuits entering the enclosure must be included in the enclosure. If a breaker is utilized for the short circuit protection that can fulfill this function, no additional hardware will be required.

3.4 Gas Meter

3.4.1 Requirements

a. The meters must comply with the applicable requirements of ASHRAE 189.1. Where conflicts occur between this guidance and the ASHRAE standard, ASHRAE 189.1 shall prevail.

b. In addition to the requirements listed below, Natural Gas Distribution and Monitoring Equipment shall be in accordance with UFGS SECTION 33 51 03.00 10. Gases are more difficult to measure than liquids, as measured volumes are highly affected by temperature and pressure. Gas meters measure a defined volume, regardless of the pressurized quantity or quality of the gas flowing through the meter. Temperature, pressure and heating value compensation must be made to measure actual amount and value of gas moving through a meter.

c. Gas distribution equipment shall be installed in accordance with all applicable federal, state and local codes and regulations.

Gas distribution equipment shall be installed in conformance with the manufacturer's recommendations and applicable sections of American Society of Mechanical Engineers (ASME) B31.8, American Gas Association (AGA) XR0104 and 49 CFR 192. Gas distribution equipment installed in areas where they will be subject to damage shall be protected by appropriate physical barriers (i.e.

bollards).

d. Natural Gas Meters shall be the Diaphragm, Rotary, or for high volume applications Turbine type with pulse output chosen to meet the specific application.

Quantity Measured: Cubic Feet of Natural Gas

Accuracy: plus or minus 1% of scale.

Resolution: minimum of 100 cubic feet of gas

Measurement Configuration: Natural Gas service to a building. For buildings that already have a gas meter with a pulse output, ensure that the pulse output is connected to a data gathering device (i.e. electric meter). For buildings where a natural gas meter already exists but does not have a pulse output, add a pulse kit to the existing meter and tie the output to a data gathering device. If the existing gas meter will not accept a pulse kit or if no meter exists a new natural gas meter shall be installed, also requiring a pulse output to a data gathering device. Ensure the pulse frequency and electronic characteristics are compatible with the existing data gathering device, if any.

3.4.2 Gas Meter Types

a. Provide gas meters for the natural gas service line to the building. Natural gas meters shall be the Diaphragm, Rotary, or for high volume applications Turbine type with pulse output chosen to meet the specific application. Temperature, pressure and heating value compensation must be made to measure actual amount and value of gas moving through a meter.

b. Diaphragm Gas Meters with flow rates less than 500 cubic feet per hour shall conform to AGA B109.1. Diaphragm Gas Meters with flow rates of 500 cubic feet per hour and higher shall conform to AGA B109.2. Rotary Type Gas Meters shall conform to AGA B109.3. Turbine Type Gas Meters shall conform to ASME MFC-4M. Meters shall be pipe or pedestal mounted and be provided with a strainer immediately upstream. Meters shall be provided with over-pressure protection as specified in ASME B31.8. Include tamper-proof protection, frost protection and fungus-proof protection as applicable. Meters shall be suitable for accurately measuring and handling gas at pressures, temperatures, and flow rates present. Meters shall have a pulse switch initiator capable of operating up to speeds of 500 pulses per minute with no false pulses and shall require no field adjustments or calibration. Initiators shall provide the maximum number of pulses up to 500 per minute that is obtainable from the manufacturer. The minimum pulse rate shall not be less than one pulse per 100 cubic feet of gas.

3.4.3 Valves and Regulators

a. Valves shall be suitable for shutoff or isolation service and shall conform to the following: Steel valves 1-1/2 inches and smaller installed above ground shall conform to ASME B16.34, carbon steel, socket weld or threaded ends with handwheel or wrench operator. Steel valves 2 inches and larger installed above ground shall conform to American Petroleum Institute (API) Spec 6D, carbon steel, buttweld or flanged ends, with handwheel or wrench operator.

b. Valves and pressure regulators are necessary at all points where pressure reduction or regulation is required by the user.

Install a shut-off valve upstream of the regulator and both upstream and downstream of the meter. Provide a gas meter bypass line with a lockable valve for buildings with critical service.

c. Service Line Regulators. Pressure regulators for individual service lines shall have ferrous bodies. Regulator shall be capable of reducing distribution line pressure to pressures required for users. Regulators shall be provided where gas will be distributed at pressures in excess of 10 inches of water column. Pressure relief shall be set at a lower pressure than would cause unsafe operation of any connected user. Regulator shall have single port with orifice diameter no greater than that recommended by the manufacturer for the maximum gas pressure at the regulator inlet. Regulator valve vent shall be of resilient materials designed to withstand flow conditions when pressed against the valve port. Regulator shall be capable of regulating downstream pressure within limits of accuracy and shall be capable of limiting the buildup of pressure under no-flow conditions to 50 percent or less of the discharge pressure maintained under flow conditions. Regulator shall have a self contained service regulator. Regulator pipe connections shall not exceed 2 inch size.

3.4.4 Gas Meter Installation

a. A shutoff valve, meter set assembly, and service regulator shall be installed on the service line outside the building, 18 inches above the ground on the riser. An insulating joint (dielectric connection) shall be installed on the inlet side of the meter set assembly and service regulator and shall be constructed to prevent flow of electrical current. A 3/8 inch tapped fitting equipped with a plug shall be provided on both sides of the service regulator for installation of pressure gauges for adjusting the regulator. All service regulator vents and relief vents shall terminate in the outside air in rain and insect resistant fittings. The open end of the vent shall be located where gas can escape freely into the atmosphere, away from any openings into the building and above areas subject to flooding.

b. Meters shall be installed in accordance with ASME B31.8. Permanent gas meters shall be installed with provisions for isolation and removal for calibration and maintenance, and shall be suitable for operation in conjunction with an energy monitoring and control system.

3.4.5 Connections

a. Connections to Publicly or Privately Operated Gas Utility Lines: The contractor shall include all materials for the connections to the existing gas lines. Final connections and the turning on of gas shall be made by the utility. The Contractor shall notify the Contracting Officer and Utility Sales Officer in writing, 10 days before final connections and turning on of gas lines. The Contractor shall make necessary arrangements with the Utility for tie in and activation of new gas lines. Only the Operating Agency/Utility Company may reactivate the system after tie in. The Contractor shall furnish to the Contracting Officer a certification by the Operating Agency/Utility Company that all Utility work has been satisfactorily completed.

b. Connection to Government Owned/Operated Gas Lines: Provide the name and location of the utility or operating agency of the existing gas lines. Show on the drawings, the location of valves to be operated for existing system deactivation. The Contractor shall provide connections to the existing gas lines in accordance with approved procedures. Reactivation of any existing gas lines will only be done by the Government. The Contractor's Connection Plan shall be submitted to the Contracting Officer and approved prior to making any connections to existing gas lines. This plan shall include the Operating Agency's required procedures which may be obtained from the Contracting Officer. The Contractor shall notify the Contracting Officer, in writing, 10 days before connections to existing lines are to be made.

3.4.6 Pressure and Leak Tests

a. Prior to returning the gas line back to service it shall be tested in accordance with ASME B31.8. Test pressures should recognize the weakest component of each system tested for the actual pressure, the maximum allowable operating pressure, and the gas supplier's maximum operating pressure. The test pressure will be 150 percent of the maximum operating pressure or 50 pounds per square inch gauge (psig), whichever is greater. However, the maximum test pressure must not be more than three times the design pressure of the pipe. The service lines shall be tested after modifications and before being placed in service using air as the test medium. Prior to testing the system, the interior shall be blown out, cleaned and cleared of all foreign materials. All meters, regulators, and controls shall be removed before blowing out and cleaning and reinstalled after clearing of all foreign materials.

b. Testing of gas service lines shall be done with due regard for the safety of employees and the public during the test. Persons not working on the test operations shall be kept out of the testing area while testing is proceeding. The test shall be made on the system as a whole or on sections that can be isolated. The test shall continue for at least 24 hours from the time of the initial readings to the final readings of pressure and temperature. The initial test readings of the instrument shall not be made for at least 1 hour after the pipe has been subjected to the full test pressure, and neither the initial nor final readings shall be made at times of rapid changes in atmospheric conditions. The temperatures shall be representative of the actual trench conditions. There shall be no indication of reduction of pressure during the test after corrections have been made for changes in atmospheric conditions in conformity with the relationship T(1)P(2)=T(2)P(1), in which T and P denote absolute temperature and pressure, respectively, and the numbers denote initial and final readings. During the test, the entire system shall be completely isolated from all compressors and other sources of air pressure. Each joint shall be tested by means of soap and water or an equivalent nonflammable solution prior to backfilling or concealing any work. The testing instruments shall be approved by the Contracting Officer. All labor, materials and equipment for conducting the tests shall be furnished by the Contractor and shall be subject to inspection at all times during the tests. The Contractor shall maintain safety precautions for air pressure testing at all times during the tests.

3.5 Water Meter

3.5.1 Requirements:

a. The water meters must comply with the applicable requirements of ASHRAE 189.1. Where conflicts occur between this guidance and the ASHRAE standard, ASHRAE 189.1 shall prevail.

b. In addition to the requirements listed below Water Meters shall be in accordance with UFGS SECTION 43 21 29. Water Meters shall be the turbine, propeller, or displacement type with pulse output chosen to meet the specific application (pipe size, flow, pressure, etc.). Water Meters shall be manufactured by Neptune, SeaMetrics, Badger Meter Inc., DLJ, or approved equal. The location of meters and meter boxes shall be shown on the as built drawings. The meters shall be centered in the boxes to allow for reading and ease of removal or maintenance.

Quantities Measured: Gallons of Water (pulse for every 10 gallons) Accuracy: 1.5% of scale.

Resolution: 1 Gallons per Minute (GPM)

Measurement Configuration: Water Supply to a building. For buildings that already have a water meter with a pulse output, ensure that the pulse output is connected to a data gathering device (i.e. electric meter). For buildings where a water meter already exists but does not have a pulse output, add a pulse kit to the existing meter and tie the output into a data gathering device. If the existing meter will not accept a pulse kit or if no meter exists, a new water meter shall be installed, also requiring a pulse output to a data gathering device.

3.5.2 Water Meter Types

a. Turbine Type Meters: Turbine type meters shall conform to American Water Works Association (AWWA) C701 Class I or Class II depending on the application. The main casing shall be bronze or cast iron protected by corrosion resistant coating with stainless steel external fasteners. Registers shall be straight-reading type, shall be permanently sealed and shall read in U.S. gallons.

Connections shall be suitable to the type of pipe and conditions encountered. Register type shall be a direct-reading remote register designed in accordance with AWWA C706 or an encoder type remote register designed in accordance with AWWA C707 but must be compatible with the local UMCS. Meters shall comply with the accuracy and capacity requirements of AWWA C701.

b. Propeller Type Meters: Propeller type meters shall conform to AWWA C704. Registers shall be straight-reading type, shall be permanently sealed and shall read in U.S. gallons. Connections shall be suitable to the type of pipe and conditions encountered.

Register type shall be a direct-reading remote register designed in accordance with AWWA C706 or an encoder-type remote register designed in accordance with AWWA C707 but must be compatible with the local UMCS. Meters shall comply with the accuracy and capacity requirements of AWWA C704.

c. Displacement Type Meters: Displacement type meters shall conform to AWWA C700. Registers shall be straight-reading and shall read in U.S. gallons. Meters in sizes 1/2 through 1 inches shall be frost-protection design as required by the local environmental conditions. Connections shall be suitable to the type of pipe and conditions encountered. Register type shall be a direct-reading remote register designed in accordance with AWWA C706 or an encoder type remote register designed in accordance with AWWA C707 but must be compatible with the local UMCS. Meters shall comply with the accuracy and capacity requirements of AWWA C700.

d. Compound Type Meters: Compound type meters shall conform to AWWA C702 and shall be furnished with strainers. The main casing shall be bronze or cast iron protected by corrosion resistant coating with stainless steel external fasteners. The main casing shall be tapped for field testing purposes. Registers shall be straight-reading type, shall be permanently sealed and shall read in U.S. gallons. The meter shall be equipped with a coordinating register. Connections shall be suitable to the type of pipe and conditions encountered. Register type shall be a direct-reading remote register designed in accordance with AWWA C706 or an encoder type remote register designed in accordance with AWWA C707 but must be compatible with the local UMCS. Meters shall comply with the accuracy and capacity requirements of AWWA C702.

e. Fire Service Type Meters: Provide Fire Service Type Meters as required by the Installation. Fire service type meters shall be proportional type or turbine type conforming to AWWA C703 and shall be furnished with strainers. The main casing shall be bronze or cast iron protected by corrosion resistant coating with stainless steel external fasteners. Registers shall be straight-reading type, shall be permanently sealed and shall read in U.S. gallons. The meter shall be equipped with a coordinating register.

Connections shall be suitable to the type of pipe and conditions encountered. Register type shall be a direct-reading remote register designed in accordance with AWWA C706 or an encoder type remote register designed in accordance with AWWA C707 but must be compatible with the local UMCS. Meters shall comply with the accuracy and capacity requirements of AWWA C703. When turbine type main line meters are used, the meter shall be supplied with a separate check valve, as a unit.

3.5.3 Water Meter Installation

a. Meter Boxes: Meter boxes shall be of cast iron, concrete, or plastic. The boxes shall be of sufficient size to completely enclose the meter and shutoff valve or service stop. Meter boxes set in paved areas subject to vehicular traffic shall be cast iron, or concrete with cast iron lid and cast iron meter reader lid suitable for vehicle wheel loads. Boxes set in sidewalks, not subject to vehicular traffic, shall be concrete with cast iron lid and cast iron meter reader lid. Plastic boxes and lids can be used in unpaved areas or grass areas not subject to vehicular traffic. Box height shall extend from invert of the meter to final grade at the meter location. The lid shall have the word "WATER" cast in it.

b. Dielectric Fittings: Dielectric fittings shall be installed between threaded ferrous and nonferrous metallic pipe, fittings and valves, except where corporation stops join mains. Dielectric fittings shall prevent metal-to-metal contact of dissimilar metallic piping elements and shall be suitable for the required working pressure.

3.5.4 Valves

a. Gate Valves Smaller than 3 Inch in Size: Gate valves that are smaller than 3 inch in size shall meet Manufacturers Standardization Society (MSS) SP-80, Class 150 and have a solid wedge, non-rising stem. Valves shall have flanged or threaded end connections, with a union on one side of the valve. Provide hand wheel operators. Valves shall open by counterclockwise rotation of the valve stem.

b. Gate Valves 3 Inch Size and Larger: Gate valves 3 inch size and larger shall meet AWWA C500 or UL 262 and be of one manufacturer. Valves shall be AWWA C500, non-rising stem type with double-disc gates or UL 262, inside-screw type with operating nut, split wedge or double disc type gate, and designed for a hydraulic working pressure of 175 psi. Valves shall open by counterclockwise rotation of the valve stem.

3.5.5 Connections

a. Connections to Publicly or Privately Operated Water Utility Lines: Contractor shall provide materials for the connections to the existing water lines. Final connections and the turning on of water shall be made by the Utility. The Contractor shall notify the Contracting Officer, in writing, 10 days before final connections and turning on of water lines. The Contractor shall make necessary arrangements with the Utility for tie in and activation of new water lines. Only the Operating Agency/Utility Company may reactivate the system after tie in. The Contractor shall furnish a certification by the Operating Agency/Utility Company that all Utility work has been satisfactorily completed.

b. Connection to Government Owned/Operated Water Lines: Provide the name and location of the utility or operating agency of the existing water lines. Show on the drawings, the location of valves to be operated for existing system deactivation. The Contractor shall provide connections to the existing water lines in accordance with approved procedures. The Contractor's Connection Plan shall be submitted to the Contracting Officer and approved prior to making any connections to existing water lines.

This plan shall include the Operating Agency's required procedures which may be obtained from the Contracting Officer.