Appendix_C_UMCS-MCX_Army_Metering_Program_Guidance_for_Advanced_Meters.pdf

UMCS-MCX

Army Metering Program

Guidance for Advanced Meters

26 May 2016

Revision 8

Note: Revision 8 deletes the reference to AWWA C706 in Paragraph 3.5 Water Meter as it no longer exists and has no replacement.

Purpose:

a. The purpose of the following guidance 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 guidance 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 1-200-02, High Performance and Sustainable Building Requirements, Paragraphs 2-4.4 and 3-4.3, Measurement, states: “All meters must be connected to a base wide energy and utility monitoring and control system using the installation’s advanced metering protocols. The installation of meters is required per DoDI

4170.11.” 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. Typically, meters are connected to a field control network utilizing either

LonTalk (ANSI 709.1-C) over TP/FT-10, Modbus RTU over EIA 485, or BACnet over EIA 485.

Generally, meters communicate over a local building-level network to a building/facility point of connection (BPOC/FPOC) which then communicates via the installation’s Network Enterprise

Center (NEC) IP network to an "Installation Level Front End", often an existing Utility

Monitoring and Control System/Energy Monitoring and Control System (UMCS/EMCS) Front-

End server. Meter data is provided to the graphical user interface for display and to any associated UMCS applications programmed to optimize operations. The data is then stored in a

Structured Query Language (SQL) database. The SQL database may be the database regularly used by the UMCS applications or a separate SQL database installed specifically for meter data.

On a regular basis the MDMS Gateway, located in the DMZ (demilitarized zone) of the installation (outside the inner firewall), or RCC (Regional Cyber Center), retrieves data from the

SQL database and sends it to the MDMS Enterprise Server.

Notes:

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

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 an electric meter digital input or controller on the network in lieu of being connected to the network themselves. Electrical meters with additional external digital inputs are allowed for other meter data collection.

c. The means for meter data transmission using open-protocols such as ANSI/CEA 709.1-C, Modbus RTU, and BACnet over Government owned transport media (LAN, telephone carrier, wireless, radio, microwave, or power line carrier, etc.) will be site specific and subject to the approval of the Network Enterprise Center (NEC). This guidance provides 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).

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 guidance refers to the system that will collect, manage, and display the meter data for the local energy manager. It may be a new system or it may consist of the existing Legacy

UMCS/EMCS and its associated building level controllers that have been upgraded with the necessary hardware/software as required. 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 guidance, 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. EPAct Section 103 requires at least daily data collection capability; and although the policy requires at least hourly, to best analyze rate data, a 15 minute recording interval is recommended. Most advanced meters offer additional features which may be attractive to system owners. Advanced meters do not offer two way communications or a kill switch for power to the facility. These functions are normally associated with smart meters.

References:

a. UFGS 25 10 10, Utility Monitoring and Control System (UMCS) Front End and

Integration

b. UFGS 26 27 13.10 30, Electric Meters - prepared by the Air Force

c. UFGS 26 27 14.00 20, Electricity Metering - prepared by the Navy

d. UFGS 33 51 13.00 30, Natural-Gas Metering - prepared by the Air Force

e. UFGS 33 12 33.00 30, Water Utility Metering - prepared by the Air Force

f. UFGS 33 63 23, Exterior Aboveground Steam Distribution - prepared by the Navy

g. UFC 1-200-02, High Performance and Sustainable Buildings

With respect to the two Electrical Metering Guide specifications and 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, edit for the specific project, 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 Electrical Metering

Specification in FY16.

h. Additional documentation noted below is available as separate electronic media files upon request. Contact the POC listed on last page.

1. Enterprise Energy Data Reporting System Security Functional Architecture Ver. 2.3.1

2. Advanced Meter Points List

3. I3A Technical Criteria Feb 2010

CONTENT OUTLINE

1.0 Installation Level Front End Computer

1.1 Open Protocol

1.2 Meter Data Storage and Point Naming Conventions

1.3 Meter Identification and Location Data

1.4 Storage of Metered Data

1.5 Workstation Display

1.6 Energy Reports

2.0 Communications

2.1 Between Meters and Installation Level Front End

2.2 Between Installation Level Front End and Enterprise MDMS System

2.3 Cybersecurity Requirements

3.0 Meters

3.1 Environmental Tolerances of Metering Devices

3.2 Advanced Meter Capability

3.2.1 Communication Protocol and Methods

3.2.2 Pulse Input Data Port Interface

3.2.3 Data Storage and Trend Logs

3.2.4 Meter Display

3.3 Electric Meter

3.3.1 Power Systems

3.3.2 Measured Values (mandatory and optional)

3.3.3 Accuracy

3.3.4 Surge Protection

3.3.5 Instrumentation (CTs and PTs)

3.3.6 Disconnects and Shorting Blocks

3.4 Gas Meter

3.4.1 Requirements

3.4.2 Gas Meter Types

3.4.3 Valves and Regulators

3.4.4 Gas Meter Installation

3.4.5 Connections

3.4.6 Pressure and Leak Tests

3.5 Water Meter

3.5.1 Requirements

3.5.2 Water Meter Types

3.5.3 Water Meter Installation

3.5.4 Valves

3.5.5 Connections

3.5.6 Disinfection

3.5.7 Tests and Inspections

3.6 Steam Meter

3.6.1 Requirements

3.6.2 Steam Meter Types

3.6.3 Steam Meter Installation

3.6.4 Piping Tests

4.0 Execution

4.1 Installation

4.2 Drawings

4.3 Scheduling of Work and Outages

4.4 Field Applied Painting

4.5 Cleanup

5.0 Testing and Checkout

5.1 Performance Verification Test (PVT)

5.2 Contractor’s Field Tests (CFT)

6.0 Training

1.0 INSTALLATION LEVEL FRONT END COMPUTER

1.1 Open Protocol. Where no existing UMCS/EMCS can satisfy the Advanced Metering Data

Management System Installation Level requirements, the design shall include a LonWorks based, BACnet based, or Niagara Framework (Tridium) based Open System Host for the front end data management system. The Open System Host shall be installed in accordance with

UFGS 25 10 10, Utility Monitoring and Control System (UMCS) Front End and Integration.

There are new open protocol building level specifications published at wbdg.org:

a. UFGS 23 09 00, Instrumentation and Control for HVAC;

b. UFGS 23 09 23.01, LonWorks Direct Digital Control for HVAC and Other Building

Control Systems; and

c. UFGS 23 09 23.02, BACnet Direct Digital Control for HVAC and Other Building Control

Systems.

These will all provide guidance on their specific communication media.

1.2 Meter Data Storage and Point Naming Conventions. The meter data shall be stored per the defined convention shown below in a full version Microsoft SQL data base for future retrieval by others. The future site Meter Data Management System (MDMS) Gateway will retrieve and re-transmit the meter data to an Enterprise Army Meter Data Management System. The contractor supplied Microsoft SQL database may be native to the Host UMCS/Metering Front-End or an entirely separate SQL database dedicated to SQL data storage. The Contractor must follow the applicable Security Configuration Guide for SQL partitioning and hardening procedures.

a. Existing UMCS systems point names vary by system capabilities and site conventions. The site naming convention must be followed where possible. Approval is required from HNC prior to alternative point name creation. This is to ensure there are no conflicts with the

MDMS gateway requirements.

b. Primary equipment names:

Servers are named EEDRS. However, the local data center server naming convention takes priority.

Building/Facility Point of Connection (BPOC/FPOC). Name is by site and building.

Use no space, period or dash unless system constraints dictate otherwise:

SiteBuilding#. Example: FTBRAGG3720

LON TP/FT10 channel names. Name in this order: Protocol Site Building#.

Example: LON Bragg 100. Note that here a space is used to separate.

c. The following point naming conventions are approved for new system installations:

SiteName is the Post name.

Building# - is the building number containing the meter; it is always the number of the building, although that building number may include a letter.

Meter - is the meter type within the building: electric, gas, water, steam; use the word

METER for electric meters and the words GAS, WATER, STEAM, BTU for the other types of meters.

Meter # - is the meter number (the nth number) within the building.

Parameter - is the name of the measured variable

For single site systems:

Building#_Meter_Meter#_Parameter

Building#.Meter_Meter#.Parameter

BLDG_2315_METER_2_VOLTS_A_B

BLDG_2315.METER_2.VOLTS_A_B

For multi-site systems, where a regional host exists:

SiteName_Building#_Meter_Meter#_Parameter

Sitename.Building#.Meter_Meter#.Parameter

Example:

HOOD_2315_METER_2_KW

HOOD_2315.METER_2.KW

Where a site area designator is required:

SiteName_Area_Building#_METER_Meter#_Parameter

Example:

Hood_A_2315_METER_2_KW

Hood_A.2315.METER_2.KW

Note: Some UMCS host software may automatically attach the Building/Facility Point of

Connection (JACEx or NAE) to the point name.

d. Provide the following meter data:

PWR_TOT Real Power (Total of Phases) KW

KWH_TOT Total KWH (Total Energy) KWH

PWR_DEMAND Demand Power KW

PWR_DEMAND_PEAK Historical Peak Demand Power KW

VOLT_A_B Rms Voltage For Phase A VOLTS

VOLT_B_C Rms Voltage For Phase B VOLTS

VOLT_C_A 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

PF_A Power Factor Phase A PF

PF_B Power Factor Phase B PF

PF_C Power Factor Phase C PF

PF_Total Power Factor Total PF

VAR or KVAR Reactive Power Power

CF Cubic Feet

GAL Gallons

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.

Fort Sample Electric Meter Information

Bldg No. Bldg Name

Bldg Sqft

Cat

Meter Name Commodity

Type

Area served by meter (sqft)

Reimburs-able (Y/N) Code

EXCH MAIN

STORE 74,053 74053 BLDG_0071_METER_1_VOLTS_A_B Electricity 74,053 y

01440

HAAF

HEALTH

CLINIC 49,679 55010

BLDG_1440_METER_2_VOLTS_A_B

Electricity 49,679 N

OPEN STR

INST 40,264 45210

BLDG_2905_METER_1_VOLTS_A_B

Electricity 40,264 N

VEH MAINT

SHOP 32,648 21410

BLDG_4541_METER_3_VOLTS_A_B

Electricity 32,648 N

06007

HAAF

ARMY

LODGING 43,732 72010

BLDG_6007_METER_1_VOLTS_A_B

Electricity 43,732 N

DEPENDENT

SCH 31,040 73046

BLDG_7560_METER_1_VOLTS_A_B

Electricity 31,040 y

7742 CO HQ BLDG 30,000 14185 BLDG_7742_METER_1_VOLTS_A_B Electricity 30,000 N

10501 CSMS/MATES 31,093 21419 BLDG_10501_METER_2_VOLTS_A_B Electricity 31,093 y

10531 CSMS/MATES 34,843 21419 BLDG_10531_METER_1_VOLTS_A_B Electricity 34,843 Y

1.4 Storage of Metered Data. The Advanced Metering Data Management System Installation

Level Front End shall store all required meter data for a minimum of two years. If data exceeds allotted space, storage shall grow automatically through database configuration changes without operator intervention.

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 (see POC on last page). The installation of wire, fiber optic cable, wireless network equipment, network switches, and/or 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 (minimum requirement: 2 single mode fibers). All IP, Ethernet, or wireless communication design and implementation plans shall be approved by the site NEC. The NETCOM Commander has directed NETCOM G3/4, G5, and G6 to support the use of all available means of communication available at sites to reduce the cost of implementing the Army’s metering program across all theaters of operation. The use of DSL, existing copper, wireless 900 Mhz radios, existing wireless 802.11 infrastructure, and dark fiber should all be considered as options before installing new copper or fiber. Coordination with NETCOM is recommended before installing new fiber.

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 guidance. 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 identifies 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 Cybersecurity Requirements

a. The process and related requirements to attain authorization for metering systems have been revised to Risk Management Framework. DoDI 8500.01, Cybersecurity and DoDI

8510.01, Risk Management Framework (RMF) for DoD Information Technology (IT) were published in March of 2014 and outline the Risk Management Framework processes.

Commands should coordinate with their local NEC to ensure compliance with the assess and authorize approach outlined in RMF. Additionally, the MCX offers guidance to shape architectural templates and influence the design process for Army installations. This document is Technical Criteria for the Installation Information Infrastructure Architecture and is available upon request from the POC.

b. The Information Systems Engineering Command’s (ISEC) Military Engineering

Directorate (MED, formerly IASED) in Fort Huachuca, AZ, has conducted testing and hardening for a limited number of metering host configurations that may assist in the development of documentation towards favorable authorization decisions. 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. Currently, the Army Metering Program has five accredited front end systems, various BPOCs, and advanced meter options, to include enterprise system level Certificates of Networthiness.

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 and network components from the Defense Information Systems Agency (DISA)

Approved Products List (APL) is encouraged, 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) Security Configuration Guide.

d. In the eyes of some security engineers, IP meters have been regarded as vulnerable and assumed to create a higher risk to the defense in depth architecture. Take note to properly configure these devices so that they do not face the internet. The IP meter interface offers a more robust transfer of data and the ability to remotely reset counters and offer time stamps.

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 cybersecurity (cybersecurity has replaced ‘information assurance’ under Risk Management Framework (RMF).

3.0 METERS

Note: Reimbursable facilities/customers that require metering devices which exceed the requirements detailed in this guidance 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.

f. Wiring: All wiring shall be UL listed.

g. Manufacturer Recommendations: The Contractor shall adhere to all manufacturer recommendations regarding wire sizing, fuse sizing, and wire types.

3.2 Advanced Meter Capability

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

b. Meters that do not provide factory advanced capabilities shall provide a pulse output for interfacing to an advanced 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 either Modbus

RTU, ANSI/CEA-709.1-C (LonTalk), or ASHRAE-135 (BACnet) protocols to the existing or new Advanced Metering Data Management System Installation Level Front End (or

UMCS/EMCS System Host). In locations where a legacy UMCS system currently exists utilizing a non-compliant communication protocol, additional protocols may be used if approved by the Government. In that case the designer should consider meters with changeable interface communication cards so that future UMCS upgrades can be accomplished with minor changes.

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 or new Advanced Metering Data Management 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, advanced 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 Power Systems. Meter 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 Measured Values: 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.

a. Mandatory Measured values

PWR-TOT Real Power KW (Total Phases)

KWH-TOT Total KWH (Total Energy)

PWR-DEMAND Demand Power

PWR-DEMAND-PEAK Historical Peak Demand Power

VOLT A-B Rms Voltage For Phase A

VOLT B-C Rms Voltage For Phase B

VOLT C-A 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

PF-A Power Factor For Phase A

PF-B Power Factor For Phase B

PF-C Power Factor For Phase C

PF-Total Power Factor Total

VAR or KVAR Reactive Power

b. Optional Measured values:

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

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 (e.g. building service entrance of 800 Amps requires 800:5 CTs for metering).

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 as 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. In addition to the requirements listed below, Natural Gas Distribution and Monitoring

Equipment shall be in accordance with UFGS SECTION 33 51 13.00 30. 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.

b. 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).

c. 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, butt-weld 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, 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 33 12 33.00 30. 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 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 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 or an encoder type remote register designed in accordance 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 or an encoder type remote register designed in accordance 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 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.

[NOTE: There is no published UFGS for the ultrasonic flow meter.]

f. Ultrasonic Flow Meter: The Ultrasonic Flow Meter must be furnished complete with matched transducers, self-aligning installation hardware and transducer cables. Ultrasonic transducers must be optimized for the specific pipe and process conditions for the application. The flow meter accuracy must +/- 1% of rate from 0 to 40 ft/sec (0.3 to 12 meters/sec). The flowmeter, must include either dry contact pulse outputs, 4-20mA, 0-10Vdc or 0-5Vdc output.

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…