Attachment F- Appendix T - Advanced Metering Infrastructure CSTO_updated.pdf

Mission Support Business Model

Configuration Standard

Technical Order

Advanced Metering Infrastructure (Rev A)

SILC-CSTO-36-11 31 17 11-01

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Commander U.S. Coast Guard Shore Infrastructure Logistics Center

300 East Main Street, Suite 800 Norfolk, VA 23510-9104 Staff Symbol: (esd) Phone: (757) 628-4277

8 October 2021

Subj: ADVANCED METERING INFRASTRUCTURE CSTO (REV A)

Ref: a) Civil Engineering Manual, COMDTINST M11000.11 (series)

b) Shore Infrastructure – Mission Support Business Model Requirements Directive

Technical Order, SILC-RDTO-36-11 29 11 00-01 (latest)

1. PURPOSE. This Configuration Standard Technical Order (CSTO) provides the framework to standardize advanced metering requirements for electricity, natural gas, propane, potable water, and non-potable water as applicable (i.e. irrigation.). The configuration established herein enables Coast Guard facilities to comply with federally mandated benchmarking and reporting requirements to optimize and reduce energy consumption and will be used to establish metering requirements across the Coast Guard’s shore infrastructure.

2. ACTION. This technical order shall be used by all design engineers (Civil Engineering Units, Facilities Design & Construction Center, and unit level Facility Engineering Departments) to plan, design, and install advanced metering for utilities infrastructure servicing “appropriate” covered buildings and tactical vehicles, such as cutters, electric government vehicles, and aircraft. Energy Managers, Water Resource Managers, Facility Engineers, Facility Asset Managers, Sector Engineering Officers, Engineering Petty Officers, and other facility managers and technical staff shall use this technical order for operation, maintenance, and to ensure that any changes made to advanced metering are in accordance with this configuration standard.

3. AUTHORIZATION. This technical order has been reviewed and is authorized by the SILC Commander.

4. DIRECTIVES / TECHNICAL ORDERS AFFECTED. A Process Guide Technical Order (PGTO) for installation and commissioning, to include a System Operational Verification Test (SOVT), is subservient to this technical order. High level process steps for installation and commissioning are outlined herein. This CSTO supersedes Advanced Metering Infrastructure SILC-CSTO-36-11 31 17 11-01.

5. ENVIRONMENTAL ASPECT AND IMPACT CONSIDERATIONS.

a. The development of this technical order and the guidance contained within it have been thoroughly reviewed by the originating office in conjunction with SILC EMD.

This guidance is categorically excluded under current Department of Homeland Security (DHS) categorical exclusion A3 from further environmental analysis in accordance with the U.S. Coast Guard Environmental Planning Policy, COMDTINST

5090.1 (series).

b. This guidance will not result in any substantial change to existing environmental conditions or violations of any applicable Federal, state, local laws relating to the

8 October 2021

Subj: ADVANCED METERING INFRASTRUCTURE CSTO (REV A) protection of the environment. All future specific actions resulting from the general guidance in this technical order must be individually evaluated for compliance with the National Environmental Policy Act (NEPA) and other applicable environmental mandates, consistent with Coast Guard Environmental Planning Policy.

6. DISTRIBUTION. SILC Business Operations Division (BOD) posts an electronic version of this technical order in CG-TIMS, and will place a link to the document in the Approved Technical Order List on SILC's Configuration Management site on the CG Portal. No paper distribution will be made of this document.

7. SCOPE. The standards described in this technical order shall be implemented in accordance the following constraints:

a. TECHNICAL AUTHORITY. The technical authority for this technical order is the SILC

Commander. Additional roles and responsibilities are identified in Section 1.4 of this technical order.

b. ASSETS / SERVICES. This technical order defines the functional configuration requirements for Utility Systems throughout the Coast Guard. Applicable assets are listed in Section 1.3 of this technical order.

8. TRAINING. Training will be available in multiple formats through the use of technical notes, job guides and job aides. These instructions are posted on the Advanced Metering CG Portal Page (http://cglink.uscg.mil/AMI). Training will be provided for the user to operate and maintain the equipment installed at each facility, as well as for the personnel that support the equipment.

9. DEVELOPMENT TEAM. The following authorities and subject matter experts were significantly involved in producing this technical order.

Name Position Organization

CDR Michael Roschel Mission Support Product Line (MSPL) Manager

CEU Providence

LCDR Mike Cost Deputy Mission Support Product Line Manager

CEU Providence

LCDR Lawrence Tormey

Mission Support Asset Line Branch Chief

SILC Mission Support Product Line

LCDR Nick Woessner Project Engineer Office of Energy Management

(CG-46)

Catherine LaBranche Asset Line Manager (ALM) / TO Author

Civil Works Asset Line

(CIVW)

Tony VanWinden Facilities Engineering TRACEN Petaluma

ETC Seth Endter Electronics Technician Chief TRACEN Petaluma

Tina Hamilton Information Technology ALM OSC Logistics Product Line http://cglink.uscg.mil/AMI

8 October 2021

Subj: ADVANCED METERING INFRASTRUCTURE CSTO (REV A)

Name Position Organization

John Regan Design Section Chief FDCC Project Execution Branch

Paul Miller Asset Line Analyst Jacobs

John Harsche Resource Efficiency Manager Tetra Tech, Inc.

10. FORMS / REPORTS. None.

11. REQUEST FOR CHANGES. Submit recommendations for TO improvements or corrections through the Engineering Change Proposal form in SILC's Configuration Management site on the CG Portal.

J. F. BARRESI

Captain, U.S. Coast Guard

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SILC-CSTO-36-11 31 17 00-01

Advanced Metering Infrastructure i

TABLE OF CONTENTS

1 Overview

1.1 Configuration Standard Summary

1.2 Advanced Meters vs Standard Meters

1.3 Applicability

1.4 Roles and Responsibilities

2 Advanced metering Selection

2.1 Qualification

2.2 Prioritization

3 Technical Requirements

3.1 Organization

3.2 Equipment Requirements

3.2.1 General Requirements

3.2.2 Electrical Meters

3.2.3 Natural Gas or Propane Meters

3.2.4 Water Meters

3.2.5 Data Acquisition Servers

3.2.6 Transceivers

3.3 Data Communications and Configuration

3.3.1 Data Communications

3.3.2 Key Data Fields

3.3.3 Recording Intervals

4 EXECUTION

4.1 Installation and Commissioning

4.1.1 Meters

4.1.2 Data Acquisition Servers (DAS)

4.1.3 Transceivers

4.2 Submittals

4.3 Maintenance

4.3.1 Electrical Maintenance

4.3.2 Gas Meter Maintenance

4.3.3 Water Meter Maintenance

5 References

5.1 Process Relationships

5.2 Referenced Documents

6 Definitions

Appendix A – Business Case Analysis ................................................................................................. A-1

Appendix B – Data Acquisition Server (DAS) Specifications ............................................................. B-1

Appendix C – Wireless ModBus/Pulse Transceiver ............................................................................ C-1

Appendix D – SAMPLE Justification and Accountability (J&A) ......................................................... D-1

Appendix E – Sample Statement of Work ..............................................................................................E-1

Appendix F – Advanced Metering Equipment Naming Convention ................................................... F-1

1 OVERVIEW

1.1 Configuration Standard Summary

The Energy Policy Act (EPAct) of 2005 and the Energy Independence and Security Act (EISA) of 2007 require metering of electricity, natural gas, propane, potable water, and non-potable water utility consumption at the building level for all federal facilities meeting thresholds as established by the Federal Energy Management Program (FEMP). Furthermore, the information (data) collected from the metering shall comply with the mandated benchmarking and reporting requirements for optimizing and reducing energy consumption in accordance with these federal mandates.

This Configuration Standard Technical Order (CSTO) will outline the specific considerations of advanced meters, which exist within the context of a larger energy management program. This program includes interactions between CG-46 and the Shore Infrastructure Logistics Center Engineering Services Division, Energy Team (SILC – ESD-Energy), Mission Support Product Line (MSPL), Engineer Officers, Engineer Petty Officers (EPOs), Facility Engineers (FEs), Design Engineers, and all other Coast Guard personnel who manage or monitor energy consumption and make use of the collected information. Figure 1-1 shows the wider context of those relationships, while Table 1-3 shows the roles and responsibilities as they pertain to this

CSTO.

Figure 1-1: AMI Program Relationships

AMI Program Responsibilities

SILC ESD Energy Team SILC BOD CG-6 FE/EPO CG-46

Design Engineer

(FDCC,

CEU,HQFE)

SILC

Product Line

Provide EDMS Requirements

Collaborate on

EDMS/Data Acquisition Interface

Support

EDMS

Server

Application

Provide Guidance for

AMI

Installation

Provide Energy

Requirements

Qualifies AMI for Inclusion in facility Design

Manage AMI Equipment

Configuration

Support AMI Data Management and

Connectivity

Support

EDMS

Application

Support

EDMS

Database

Oversees

AMI

Installation

Report Savings Achieved through AMI

Develops/ or Includes

Plans and Specifications for AMI Installations

Support AMI Hardware

Requirements

Prioritizes AMI Projects Perform

Energy Audits Through REMs

Support AMI Data

Management

Support

EDMS

Client

Perform AMI Maintenance

Perform Energy Analysis

Manage Network at

Site

Perform Energy

Analysis

1.2 Advanced Meters vs Standard Meters

It is important to differentiate the advanced meter equipment detailed herein from standard energy and consumption meters. The latter are electromechanical or solid state meters that cumulatively measure, record, and store aggregated usage data that are periodically retrieved for use in customer billing or energy management. In contrast, advanced meters 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 metering system. These advanced meters commonly measure every 15 minutes to match utility billing intervals. Other intervals (e.g., 1 minute, 5 minute, hourly) can be accessed and are useful for examining equipment performance, trending, and start/stop characteristics. Measuring consumption, collecting data, and analyzing at the whole building, sub-panel, or even specific end-use levels allow for effective decision making to best maintain systems and ultimately reduce utility consumption through awareness and optimizing equipment performance.

Most United States Coast Guard (USCG) sites and facilities were originally constructed with utilities measured via standard usage meters only at incoming site area or within other agency jurisdictions. These meters are known as master meters and only track cumulative usage of multiple buildings at infrequent intervals. This level of usage metering does not comply with the federal mandates for detailed tracking of specific facilities (buildings, shore ties, equipment etc.).

While advanced metering for steam is recommended at the building level per federal guidance, there is not a business case for advanced metering of steam within Coast Guard facilities.

Similarly, fuel oil consumption is consistent only with standard metering. As these do not require advanced interval based consumption measurements, steam and fuel oil are not referenced in this CSTO.

The configuration for the Advanced Metering System documented in this CSTO began from the initial phase of the Advanced Metering Infrastructure (AMI) Project in 2012. During this initial implementation period, equipment from Obvius LLC., an energy solutions provider, was selected as the standard configuration for Data Acquisition Servers (DAS) and transceivers.

Over 2,000 advanced electrical meters were installed in Coast Guard buildings at appropriate assets – buildings equal or greater than 5,000 square feet (SF), buildings with high energy use, select family housing and tactical assets (e.g., shore ties, electric government vehicles, and aircraft).

1.3 Applicability

This technical order applies to utilities assets, as defined by the USCG Facilities Classification Guide, and listed in Table 1-1. Table 1-2 defines the Advanced Metering Equipment and associated Level IV Uniformats.

Facilities which are required to be metered with advanced meters shall be determined through Qualification and Prioritization processes as described in Section 2.

Table 1-1: Applicable Assets Listed by CATCODE

CATCODE CATCODE Description 811-46 Electric Power - Wind Turbine 811-48 Alt Energy Source Power not Solar/Wind 811-50 Solar Array or Photovoltaic System 812-01 Electrical Distribution System 812-31 Electrical Power Distribution Line, Overhead 812-32 Electrical Power Distribution Line, Underground 822-12 Heat Distribution Line 824-10 Heat Gas Distribution Line 827-20 Chilled Water and Refrigerant Distribution Line 842-10 Water Distribution Line, Potable 843-10 Water Distribution Line, Fire Protection 845-20 Water Distribution Line, Non-Potable

Table 1-2: Applicable Equipment Uniformat

Uniformat Equipment Description Feature ID D509081 Data Acquisition Server DAS D501081 Electrical Advanced Meter EAM D301081 Gas Advanced Meter GAM D202081 Water Advanced Meter WAM D509082 Transceiver (Modhopper) XCVR D509083 I/O Flex Module IOM

1.4 Roles and Responsibilities

The technical authority for this configuration standard is the SILC Commander. Table 1-3 enumerates the roles and responsibilities for establishing the standards defined in this technical order. The following “RASCI” codes are used:

R - Responsible – Those who do the work (typically only one Responsible per task).

A - Approver – The one ultimately accountable for the deliverable or task (must have only one Approver per task).

S - Supports – Those who provide resources, information, expertise or other assistance in completing the task.

C - Consulted – Those whose opinions are sought (two-way communications).

I - Informed – Those who are kept up-to-date on progress (one-way communication).

Table 1-3: Roles and Responsibilities

Task, Deliverable, or Responsibility SI

LC

BO

D

SI

LC

ES

D

- E ne rg y M

SP

L P ro du ct Li ne M an ag er

Ci vil

W or ks A ss et

Li ne

M an ag er

De sig n En gin ee r

FE

/E

PO

CG

-4

Co nt ra ct or

CG

-6

Establish Configuration Standards I C A R C C S S Manage Utilities Configuration A R C C Qualify and Prioritize Metering Projects

A/R C R

Manage Equipment Installation C A R I Perform Maintenance A I R Manage Network Infrastructure A C I I R

2 ADVANCED METERING SELECTION

Selection of advanced metering shall undergo a two-step process. The first step is to qualify which facilities or assets are required and appropriate or fiscally reasonable to meter (MSPL should be consulted when making this decision). The second step is to prioritize the list of metering projects or responsibilities.

2.1 Qualification

The factors of utility qualification for advanced metering are comprised from federal mandates, and generally include requirements for installation at “appropriate assets” defined as covered buildings, smaller facilities, equipment necessary for optimization of building operations, selected family housing communities, and connections for tactical assets. Key federal guidance includes the Energy Act of 2020, the Energy Policy Act of 2005 - Section 103, EISA 2007, and the Federal Energy Management Program for Metering Best Practices.

Department of Homeland Security and Coast Guard guidance include Shore Facilities Utilities Metering Guidance Memorandum, and the U.S. Department of Homeland Security Metering Plan (See Section 5.2 Referenced Documents).

Coast Guard guidance specifically requires that advanced meters meet the full intent of EPAct 2005 and shall be installed on any new construction or major renovation of $200,000 or above in facilities that meet thresholds listed in Table 2-1 or Table 2-2. All shore ties and new renewable energy projects are included in this guidance. Specifically, the guidance dictates that advanced meters shall be included as an Energy Conservation Measure (ECM) in the Energy Savings Performance Contracts (ESPC)/ Utility Energy Service Contracts (UESC) projects – FEMP Operations and Maintenance Best Practices 3.0. Electric Vehicle (EV) charging stations shall be metered. Meters shall be installed to capture all EV charging stations at a site where practicable. For example, if ten EV charging stations are fed from one main distribution panel (MDP), then an AMI electric meter should capture the entire MDP. Further EV guidance may be found in Electric Vehicle Support Equipment (SILC-CSTO-36-11 31 17 11-02). Metering of Privately Owned Electric Vehicles (PEV) are addressed in ALCOAST COMDT NOTICE (ACN) 032/21.

Additionally, the guidance calls for a concentrated effort to meter building energy consumption on a sub-building level through sub-metering for certain building types (such as data centers) since energy use has increased significantly over the years in these facilities. Water meters shall be installed based on water use and flow at the whole building level. The water meters should comply with the Department of Energy’s Best Practices for potable and process water use reporting requirements. Additionally advanced water meters are required for specialized use (such as central boiler or chilled water plants) and high water use activities (such as piers and vehicle washing stations).

Figure 2-2 provides a decision matrix to guide the selection of applicable assets. The first step of selection involves potential inclusion/exclusion criteria to advanced metering. These include facilities or assets that will be removed from inventory, whether the operational security of the facility is such that data collection would be disallowed or problematic, etc. The thresholds for advanced metering are summarized in Table 2-1 and Table 2-2, adapted from the U.S.

Department of Homeland Security Metering Plan, November 2015. Appendix A provides the Business Case for determining practicability for installation of an advanced meter.

Figure 2-2: Facility Qualification Decision Matrix

Table 2-1: Advanced Energy (Electricity and Natural Gas / Propane) Meter Thresholds*

Facility Function Real Property Use or

Category Code

Size SF (Greater than or Equal)

All Other Land ** 80 5,000 Communications Systems 72 5,000 Dormitories/Barracks 31 5,000 Hospital 21 5,000 Housing (Individual Unit) 30 5,000 Industrial*** 50 5,000 Laboratories 74 5,000 Museum 28 5,000 Aids To Navigation(ATON) and Traffic Aids 73 5,000 Office Building Locations 10 5,000 Other Institutional Uses *** 29 5,000

Facility Function Real Property Use or

Category Code

Size SF (Greater than or Equal)

Post Office 14 5,000 School 23 5,000 Service (other than buildings) **** 60 5,000 Warehouses 41 25,000 Pier/Wharf (one meter per shore tie) 151-20 Cutters (65’ & greater) Pier/Wharf (master meter for all shore ties) 151-20 Other Vessels Electric Vehicle (EV) Charging Stations (master meter for all stations) 812-32 One or more EV’s

Aircraft Hangar 211-05 25,000 Exchange Eating Facility 740-04 1,000 Cold Storage Building 740-24 1,000 Recreation Center 740-28 1,000 Bowling Center 740-40 1,000 Golf Club House and Sales 740-80 1,000

* Or as practicable – See Appendix A ** Except 740 Category Codes (CATCODE) listed in this table *** Some facilities < 5,000 may require metering pending energy analysis **** Except hangars (211-05)

Table 2-2 Advanced Water Meter Thresholds*

Facility Function Water Usage Pier/Wharf (one meter per shore tie) Cutters (65’ & greater) Pier/Wharf (master meter for all shore ties) Other Vessels Large Water Using Process > 1,000 gal/day per billing period** Irrigated Landscape Area > 25,000 square feet All Building Functions > 5,000 square feet > 1,000 gal/day per billing period**

* Or as practicable – See Appendix A **Use consumption values from design calculations for facility or process

2.2 Prioritization

For the purpose of maximizing cost effectiveness, it is recommended that the installation of advanced energy (electricity, water, and natural gas) meters be prioritized using the hierarchy as follows per Federal Building Metering Guidance and Coast Guard Metering Plan:

Energy Metering (Electric and Natural Gas / Propane)

1. New Construction and Major Renovations ($200,000 or greater).

2. Inclusion on the Energy Independence and Security Act (EISA) Audit Covered facilities list.

3. Shore Ties (aka Cold Iron).

4. Electrical Vehical charging stations as a whole.

5. Buildings that have been targeted with ESPC or UESC / resource conservation projects.

6. All agency data centers not planned for consolidation or closure.

7. All other known energy-intensive building types (e.g., laboratories, hospitals, control towers, and food services).

8. All individual buildings 10,000 SF or above.

9. All large energy-consuming mission support processes (training systems, industrial systems, communication transmitters, ship cold iron services, etc.).

10. All High Performance and Sustainable Buildings, if not already captured above.

11. Remainder of “appropriate” buildings, largest first - 5,000 SF or above.

Water Metering

1. New Constructions and Major Renovations ($200,000 or greater).

2. Covered facilities that are known to be the largest water consumers.

3. Shore Ties.

4. Buildings that have been targeted with resource conservation projects.

5. All well water and other internal supply lines to the installation (campus).

6. Sufficient meters or other leak detection devices on distribution lines to effectively identify system losses. Prioritize the largest distribution lines first.

7. All water-intensive facilities including chiller plants, barracks, galleys/kitchens, dining facilities, swimming pools, gyms, golf courses, piers, dry docks, laundry facilities, vehicle wash stations, industrial facilities, hospitals, prisons, water-intensive laboratories, and large landscape systems.

8. All large individual building – 10,000 SF or above.

9. All High Performance and Sustainable Buildings, if not already captured above.

10. Remainder of “appropriate” buildings, largest first - 5,000 SF or above.

3 TECHNICAL REQUIREMENTS

3.1 Organization

The technical requirements section delineates the equipment and software considerations of the Advanced Metering Infrastructure for utilities. Section 3.2, Equipment Requirements, describes the functional standards when implementing a Utility Advanced Metering System. This section is subdivided by type of utility to be metered and system elements that are common across utility types. Section 3.3, Data Communication and Configuration, describes the standard data elements required to support an Energy Data Management System (EDMS) software tool.

Figure 3-3 illustrates the Typical Advanced Metering System Diagram for the USCG.

3.2 Equipment Requirements

The specific requirements for gathering consumption data from discrete sources (electrical panels, buildings, vessel shore ties, pipes, etc.) are unique among utilities and will be detailed for each utility type in Sections 3.2.1 through 3.2.4. The transceivers that collect the source metered data and the data acquisition servers through which the metered data is routed are common across utilities type and will be detailed in Section 3.2.6 and Section 3.3 respectively.

3.2.1 General Requirements

Meters installed shall be compatible with the Data Acquisition Server (DAS). As of 2017 the DAS’s in place are Model A8812, manufactured by Obvius, LLC.

3.2.2 Electrical Meters

3.2.2.1 Introduction

This section discusses the most common electrical metering parameters, focusing on parameters that offer the greatest potential for energy and operational efficiency improvements in accordance with the Federal Energy Management Program. Advanced Metering consists of metering components and wireless technology that transmit time interval consumption data from discrete sources (electrical panels, buildings, vessel shore ties, etc.) to a networked solution for storage, monitoring, and analysis via an EDMS.

WARNING! Electricity metering can be a complicated and dangerous endeavor; the equipment and procedures discussed here should only be attempted per personnel rating and training in accordance with the Safety and Environmental Health Manual, COMDTINST M5100.47 (series), in compliance with the current edition of National Fire Protection Association (NFPA) 70: National Electrical Code (NEC), and any local or agency-specific codes or requirements.

3.2.2.2 Electrical Meter Equipment Specification

Standard Configuration A. The power meter shall be capable of measuring the variables listed in Section 3.3.2.

B. The power meter shall be sized equal to or greater than the circuit’s Overcurrent Protection Device (OCPD), i.e., circuit breaker.

C. The power meter shall support capture of variables at the interval defined in Section 3.3.3.

D. The meter shall report serially over an RS-485 network using the Modbus Remote Terminal Unit (RTU) protocol.

E. The power meter shall consist of the required number of solid or split-core current transformers (CTs). Split core CTs shall be hinged at both axes with the power metering electronics embedded inside of the master CT.

F. The meter shall measure demand in kilowatt (kW) and consumption in kilowatt hour (kWh).

G. The consumption (kWh) variable shall be stored in non-volatile memory and retained in the event of a power outage.

H. The meter shall directly accept any voltage input from 120-480 VAC.

I. The meter shall be calibrated as a system and be accurate to +/- 1% from 5% to 100% of the rated current over a temperature range of 0-60 C.

J. The meter shall conform to American National Standards Institute (ANSI) C12.1 metering standards.

K. The power meter shall be internally isolated to 2000 VAC.

L. The power meter case isolation shall be 600 VAC.

M. The power meter series shall have models available for Amperage ranges of 10-2400

Amperes.

N. Consumption meters on shore ties and exterior panels shall have a watertight protective housing.

O. The meter shall include specifications for any peripherals required.

Alternate Configuration In situations where panels have a lack of space available or if power entering panel exceeds the capacity of the Standard Configuration (480 VAC, 2400 Amperes), alternate metering solutions that meet the requirements of standard configuration will be considered as follows:

A. Current Transformer (CT) options:

1. Split Core Flexible CTs are encapsulated in silicone rubber allowing for movement when placing in a panel with minimal space. The CT’s are available in both round and rectangular shapes.

2. Flexible Rope CTs have two parts, the flexible coil and compact power and energy meter. The flexible coil is shaped like a rope and fits in extremely tight spaces. The flexible coil is not a self-contained metering unit. The flexible coil is hard-wired into the power and energy meter where it transmits the data to the DAS via a Modhopper Transceiver.

3.2.3 Natural Gas or Propane Meters

3.2.3.1 Introduction

Per the Shore Facilities Utilities Metering Guidance Memorandum, natural gas or propane meters depend on the application, flow rate, installation access, and desired accuracy of the meter. Therefore meters shall be installed that compensate for density variations between standard and actual conditions for accurately defined flow rates.

Improving energy systems within the Coast Guard rests, in part, on detailed knowledge of current energy use. That in turn, depends on metering not only sources of electricity and chilled water, but also monitoring natural gas or propane mass flow and consumption.

By monitoring the flow rate and consumption, it becomes possible to identify unusual consumption points, encourage conservation, reduce energy costs, and minimize environmental impact. Thermal Mass flow metering can provide cost allocations to differing operating areas, ascertain aging issues of process equipment such as boilers or furnaces, and identify possible leaks in fuel feed lines.

3.2.3.2 Gas Meter Equipment Specification

A. The gas meter shall be capable of measuring the variables listed in Section 3.3.2.

B. The gas meter shall support capture of variables at the interval defined in Section 3.3.3.

C. Regional natural gas utilities will often change a standard, analog meter to an advanced meter with customer pulse output for a flat fee. This is the preferred option to capturing USCG natural gas consumption. Additionally, third party pulse initiators may be used on existing analog gas meters; this is the second preferred method to avoid installing a new gas meter on a line. Permission must be obtained to install a device on a utility owned gas meter.

D. The meter shall report serially over an RS-485 network using the Modbus (RTU) protocol.

E. The thermal mass flow meter shall be used to measure and totalize the flow of natural gas or propane.

F. The flow meter shall accept an input power of 24 volts direct current (VDC) and output a 4-20 milliamp (mA) signal of the flow rate along with a pulse output.

G. Flow meter shall be rated for use in Class 1, Division 2 hazardous area, per NEC.

H. Probe and retractable device shall be suitable for the operating pressures of the utility.

I. The thermal mass flow meter shall be calibrated using the actual gas or gas mixture used in the installation. Air equivalency calibrations shall not be accepted.

J. Calibration system shall be National Institute of Standards and Technology (NIST) traceable.

K. The flow meter shall be factory configured for the specified flow rate and pipe size to permit it to be installed and placed into operation without need for any additional field setup.

L. The supplier of the thermal mass flow meter shall present a method of verifying that the flow meter is within original calibration; this test shall be performed without having to remove the flow meter from the pipe.

3.2.4 Water Meters

3.2.4.1 Introduction

Selection criteria for water meters are based on size of pipe. The specific metering option chosen will depend on a number of factors including, but not limited to, current design, life cycle costs, accuracy requirements, resolution, minimum flow rate, potable versus non-potable, range of flow rates, and maximum flow rate. Cooling towers are especially important for metering as this represents reclaimed water and is not billed for sewer.

3.2.4.2 Water Meter Equipment Specification

Water Meters

A. The water meters shall comply with the most current Executive Order (EO) requirements for potable and process water use reporting requirements.

B. Water meters shall be a Positive Displacement or Ultrasonic (UT) Meter type.

C. Third party pulse meters may be used on existing analog water meters. This approach is preferred to installing a new meter to save money and reduce interuptions in the building water. Permission must be obtained by the local utility prior to placing any third party device on a utility meter.

D. Positive Displacement Meters must be installed horizontally. UT Meters must be installed on a long, straight run to ensure laminar flow; see manufacturer’s instructions for minimum straight run length. Additionally, UT meters must be calibrated post installation.

E. The water meters shall be capable of measuring the variables listed in Section 3.3.2.

F. The water meters shall support capture of variables at the interval defined in Section

3.3.3.

G. The water meters shall report serially over an RS-485 network using the Modbus (RTU) protocol.

H. The water meters shall operate within the pipe size range of the site.

I. The water meters shall be constructed of rugged bronze or thermoplastic housing.

J. The water meters shall have a minimum accuracy of +/- 1.5%.

K. The water meters shall have repeatability of +/- 0.5%.

L. The water meters shall support a Maximum Operating Pressure of 150 pounds per square inch (psi).

M. Pulse output, if present, must be 2x, dry contact relay for consumption values.

N. Pulse Transmitter, if present, shall have:

1. Six-digit, non-resettable, straight reading odometer/totalizer.

2. 360° test circle sweep hand.

3. Flow finder to detect leaks.

Chilled Water/Hot Water Energy Meter

A. These shall be installed for centralized chill/heat systems and large distributed systems, and may be installed for small, residential grade systems.

B. The water meters shall be capable of measuring the variables listed in Section 3.3.2.

C. The water meters shall support capture of variables at the interval defined in Section

3.3.3.

D. The water meters shall report serially over an RS-485 network using the Modbus (RTU) protocol.

E. The water meters shall be suitable for metering cold or hot systems.

F. The water meters shall compute energy using flow and temperature differential.

G. The water meters shall integrate the flow and temperature data to compute flow/energy rate and total.

H. RTU System shall include the following:

1. Resistance Temperature Detector (RTD) meets International Electrotechnical Commission (IEC) 751 Class B.

2. Electrical Inputs meet RS-485.

I. The system shall operate within the pipe size range of the site.

J. Tee shall be constructed from cast bronze.

K. Hot liquid sensor shall have continuous operating temperature of 40° to 260°F [4° to

125°C].

L. Chilled liquid sensor shall have continuous operating temperature of -4° to 140°F [-20° to

60°C].

M. Outputs shall accommodate:

1. Scaled pulse output. Solid state switch. Maximum frequency of scaled pulse varies based upon pulse width selected. Pulse width available is 10, 50, 150, 200, 250, and 500 millisecond (mS). Resulting frequency range is 0.01 Hz min. to 100 Hz max.

2. Signal can travel up to 2000 feet (610 meters) between flow sensor and connected device depending on cable.

N. Standard flow measurement range shall be 0.6-6 meters per second (mps) [1.97 to

19.69 feet per second (fps)].

O. Low flow measurement range shall be 0.09-2.5 mps [.295 to 8.2 fps].

P. Accuracy shall be +/- 2% of full scale.

Q. Repeatability shall be +/- 0.5% of full scale.

R. Shall be suitable for clean, homogenous, lower-viscosity liquids, including glycols.

S. All meters shall be calibrated and tested in factory to an IEC 751 Class B accuracy.

Line-Powered Flow Sensor

A. Water meters installed shall be compatible with DAS Model A8812 (manufactured by Obvius, LLC.) capable transceivers or equivalent depending on the contract requirements in place.

B. The water meters shall be capable of measuring the variables listed in Section 3.3.2.

C. The water meters shall support capture of variables at the interval defined in Section

3.3.3.

D. The meters shall report serially over an RS-485 network using the Modbus (RTU) protocol.

E. The system shall operate within the pipe size range of the site.

F. Liquid sensor shall have continuous operating temperature suitable to the water and site conditions.

G. Line-Powered, Insert-style Impeller Flow Sensor, Liquid, Single-Channel:

1. Sensor type shall be either direct insert or hot tap.

2. Capable of fitting multiple pipe diameters within the specified range of pipe diameters at the site.

3. Hot tap versions can be removed or reinstalled without removing sensor housing from the piping.

H. The meter shall have the following System Components:

1. Impeller Flow Sensor.

2. Mounting Hardware.

3. Single-directional or Bi-directional versions.

4. Tap size shall be 1'' National Pipe Thread.

5. Sensor material shall be constructed from 316 stainless steel or Brass, B16, UNS

C36000 (not available for hot tap versions).

I. Pressure drop shall be 0.5 psi or less at 10 fps for pipe diameters of 1.5'' (3.81 cm) and larger.

J. Detection Technology: Unidirectional versions shall use non-magnetic detection technology; bidirectional versions shall use magnetic detection technology.

K. Enclosure shall be National Electrical Manufacturers Association (NEMA) 4X.

L. Sensor Performance:

1. Measuring range shall be 1 to 20 fps (.30 to 6.1 mps).

2. Accuracy shall be +/- 1% of full scale.

3. Repeatability shall be 0.5% of full scale

3.2.5 Data Acquisition Servers

3.2.5.1 Introduction

Functional requirements of the Data Acquisition Server are specified below. For DAS specifications, see Appendix B.

3.2.5.2 Data Acquisition Server Requirements

The Data Acquisition Server requirements are as follows:

A. The DAS shall be an Obvius AcquiSuite® Model A8812, Model A8810, or equivalent.

The DAS is the brain of the system, and it is important to keep consistency within each facility and throughout the USCG. See Appendix D for draft Justification and Accountability (J&A).

B. The DAS must be compatible with all new advanced metering points.

C. The DAS shall be a standalone wall-mounted device powered by a 120V wall transformer.

D. The DAS shall accept up to 32 ModBus device inputs (or specified maximum from manufacturer’s recommendation) on the RS 485 serial input terminals. The DAS shall provide automatic recognition and configuration for ModBus power meters as well as other ModBus devices (see below).

E. The DAS shall accept up to 8 inputs directly. Each input shall be capable of being configured for the following:

1. 0-10 Volt - Min/Max/Average/Instantaneous.

2. 4-20 mA - Min/Max/Average/Instantaneous.

3. Pulse - Consumption, Rate.

4. Resistance - Min/Max/Average/Instantaneous.

5. Runtime - Runtime, Status.

F. The DAS shall provide automatic recognition and configuration of ModBus devices.

G. The DAS shall provide user interface via standard web browser using an integrated ethernet RJ45 jack.

H. The DAS shall provide time stamping of measured values from all devices on user selected intervals from 1 to 60 minutes.

I. The DAS shall be capable of creating virtual meters and log from the virtual meter.

J. The DAS shall provide alarm set points for all measured values including the option for either high/low or warning/alarm.

K. The DAS shall be capable of using Local Area Network connections (static Internet

Protocol or Dynamic Host Configuration Protocol), external telephone modem or external cellular modem (GSM) for data upload.

L. The DAS shall provide data in standard delimited text form (.txt).

M. The DAS shall provide the option for retrieving data using Extensible Markup Language

(XML).

N. Data uploads shall be either push or pull at the option of the user, on user selected intervals.

O. The DAS shall be capable of (4) upload channels.

P. The DAS shall store all recorded variables in non-volatile memory.

Q. The DAS shall function as a gateway device, using ModBus TCP to retrieve specific data from connected devices as required and BACnet IP.

R. The DAS shall have remote access feature capability for remote configuration, firmware updates, and modifications to upload channels, and other settings.

3.2.6 Transceivers

3.2.6.1 Introduction

Functional requirements of metering transceivers are specified below. For transceiver (Modhopper) specifications, see Appendix C.

3.2.6.2 Transceiver Requirements

The transceiver requirements are as follows:

A. The wireless MODBUS/Pulse Transceiver shall be a ModHopper R9120-5 or equivalent.

B. The transceiver shall be a standalone wall-mounted device powered by a 120V wall transformer or 9-30VDC.

C. The transceiver shall operate in one of the Instrumentation, Scientific, and Medical (ISM) radio frequencies (900 MHz).

D. The transceiver shall transmit at 1W power.

E. The transceiver must be installed without the need for a site license.

F. The transceiver shall be frequency hopping spread spectrum (FHSS) protocol to avoid interference.

G. The transceiver shall communicate with other transceivers to develop a self-managing mesh network without the need for a host computer or software to manage the network.

H. The transceiver network shall be designed to optimize transmission of ModBus RTU protocol data packets such that the wireless data stream is transparent to the ModBus RTU master.

I. The transceiver shall have one RS 485 port for serial communications and two auxiliary terminals for pulse inputs.

J. Each transceiver shall provide the following status indications:

1. Alarm.

2. RF RX (Receive).

3. RF TX (Transmit).

4. 485 RX (Receive).

5. 485 TX (Transmit).

6. Alive.

7. Pulse 1.

8. Pulse 2.

9. 400MHz.

K. Each transceiver shall provide the capability for signal strength indication using the Pulse 1 and Pulse 2 Light Emitting Diodes (LEDs) listed above and a push button mounted on the transceiver with no external interface.

L. The transceiver network shall continuously monitor the performance of the network to optimize the routing of transmissions from connected devices to the ModBus master and adjust routes to optimize throughput.

M. The transceiver must perform up to a maximum range of 3,000 feet indoors, without line-of-sight and up to 14 miles with line of sight.

N. The transceiver must utilize 256 bit Advanced Encryption Standard (AES) technology.

O. The RS-485 cable which connects the meter with the wireless transceiver, and the data acquisition server with the wireless transceiver, shall be 600V, 1pr, 18awg, stranded, foil shield, polyvinyl chloride (PVC) jacket.

P. All Cables to be continuous with no cable splices.

Q. If Remote or external Antenna (e) is required, the location shall be line of site with continuous cable. The type of Antenna (e) shall be designed for outdoor use and most extreme weather conditions.

3.3 Data Communications and Configuration

3.3.1 Data Communications

As data is collected, it shall be communicated to a common repository for storage and analysis similar to that shown in Figure 3-3. This section details the system that shall be used to collate and communicate the individual streams of metered data at a facility/site prior to being processed into a central repository (labeled as “Equipment” in Figure 3-3 below). This equipment is comprised of meters, transceivers, and the DAS. The equipment was selected and vetted during the initial implementation of the Advanced Metering Infrastructure (AMI), (see Appendix D). As such, all AMI equipment installed to date should adhere to the requirements of this CSTO. The Enterprise/Network Services and End User Applications are beyond the scope of this Technical order. However, the energy variables collected by the equipment described herein (which is then made available to the Enterprise/Network services and End User Applications software) in Section 3.3.2 Key Data Fields.

Figure 3-3: AMI System Diagram

The information gathered by the above systems is collected, analyzed, and archived by an EDMS software tool. While the EDMS is configured through a separate set of prescribed Information Technology (IT) documentation, as outlined in Shore Facilities Utilities Metering Guidance Memorandum, the needs of that software both informs and is informed by the configuration standards set for in this technical order. As such this section documents the data fields that shall be supported through the selected EDMS. The format of the data feeds into the EDMS shall be in text form via standard delimited text, or XML format per Section 3.2.5.2 DAS requirements.

3.3.2 Key Data Fields

Key data fields are shown in the tables below.

Table 3-1: Electric

Variable Unit Energy consumption kWh Rate of energy Consumption (Power) kW Real Power kW Reactive Power kVAR Apparent Power kVA Power Factor (Ratio of Real Power/Apparent Power)

Voltage, Line to Line Volts

Variable Unit Voltage, Line to Neutral Volts Current Amps Average Demand kW Minimum Demand kW Maximum Demand kW Device Number NUMERIC Device Type TEXT Status TEXT Date/Time of last upload DATE/TIME Date/Time of last reading DATE/TIME Site TEXT Sector TEXT Location Description TEXT Location Number (RPUID) NUMBER

Table 3-2: Gas

Volumetric Consumption therms/hour Gas Ave Rate therms/hour Gas Instantaneous Rate therms/hour Gas Min Rate therms/hour Gas Max therms Device Number NUMERIC

Device Type TEXT

Status TEXT

Date/Time of last upload DATE/TIME

Date/Time of last reading DATE/TIME

Site TEXT

Sector TEXT

Location Description TEXT

Location Number NUMBER

Table 3-3: Water

Volumetric Consumption GPM Water Average Rate GPM Water Instantaneous Flow Rate GPM Water Min Rate GPM

Water Max Flow Rate GPM Device Number NUMERIC

Device Type TEXT

Status TEXT

Date/Time of last upload DATE/TIME

Date/Time of last reading DATE/TIME

Site TEXT

Sector TEXT

Location Description TEXT

Location Number NUMBER

3.3.3 Recording Intervals

Recording intervals shall conform to latest release of U.S. Department of Energy Metering Best Practices (release 3.0 or later). Recorded time intervals will be 15 minutes to match common utility billing meter intervals, or as otherwise established by SILC. Other user-specified time intervals (e.g., 1 minute, 5 minute), shall be supported for examining system or equipment performance, trending, and start/stop characteristics. The advanced meters shall have the capability to use remote or automated meter reading (AMR).

4 EXECUTION

4.1 Installation and Commissioning

General

A. Prior to the installation of the equipment, the contractor shall provide the Coast Guard with the number of DAS’s, metering devices and transceivers to be installed;

additionally, they shall propose device names to the USCG. Upon receipt of the information, DAS, meter and transceiver device names will be approved by the Coast Guard.

B. All equipment shall be installed per manufacturer’s instructions with latest firmware and shall comply with NEC standards, industry specifications and standards and local codes for performance, reliability, compatibility and security (see Technote 88 Security Best Practices - Table 5-3.) The latest installation manuals and best practices for the DAS and Transceivers can be found on the CG AMI Portal – http://CGlink.uscg.mil/AMI or www.obvius.com.

C. Install equipment rigidly and adequately for the operating environment. This includes the use of blocking for support and special fasteners if necessary to ensure tight and secure mounting of equipment. RS485 cable, power cable, and any other wires shall be neatly routed and secured resulting in a neat, orderly appearance. RS485 wiring shall be protected from abrasion upon passing through electrical panel cutout or hole.

D. No wires shall be installed running along/up the exterior façade. All wires shall enter the building and run internally in wall systems or service rooms.

E. All equipment installed to include associated cabling and hardware shall be weather resistant or installed in a weather resistant enclosure per manufacturer’s instructions.

F. Upon final installation, equipment shall not interfere with panel boards or switchgear covers or doors.

G. The contractor shall ensure that the DAS, cellular modem, and transceivers (ModHoppers) are connected to an existing or new 110-120VAC power supply.

H. Programming of the equipment shall be in accordance with the manufacturer’s Installation and Operation Manual. The Coast Guard will provide the contractor with access to the existing DAS as applicable, to obtain the existing ModBus addresses, radio channel, and other pertinent information.

I. DAS’s, Transceivers and Meters shall be numbered. The numbering scheme shall be in accordance with Appendix F - AMI Equipment Device Naming Convention, and be approved by the Coast Guard prior to installation. Each DAS, I/O Flex Module and transceiver installed shall be physically labeled with the corresponding number.

J. If removal of existing advanced metering components is necessary as part of the scope of work, the Contractor shall reuse existing equipment where possible and return unused equipment to the Facilities Engineer (FE) or Engineering Petty Officer (EPO). Wall finish will be restored to original condition or better (patched and painted to match surrounding finish) for any equipment removed.

K. The Contractor shall arrange for a representative from Obvius, LLC to be on-site for final system configuration as part of any contracts to install metering equipment.

http://cglink.uscg.mil/AMI http://www.obvius.com/

L. The unit shall notify the USCG SILC ESD Energy Branch and MSPL when metering system is installed, updated, or replaced.

4.1.1 Meters

General

A. All equipment shall be installed in strict compliance with the manufacturer's instructions and shall include commissioning into the Acquisition Server system.

B. The meters supplied shall be integrated into the Coast Guard’s utility monitoring system.

C. Meters procured by the contractor must be compatible with the AcquiSuite firmware.

(Firmware version v02.15.0226 and newer).

D. The meters shall include specifications for any peripherals required.

E. Ground exposed, non-current-carrying metallic parts of electrical equipment, metallic raceway systems, grounding conductor in metallic and nonmetallic raceways, telecommunications system grounds, and grounding conductor of nonmetallic sheathed cables, as well as equipment to eliminate shock hazard and to minimize ground loops, common-mode returns, noise pickup, cross talk, and other impairments.

Electric

A. In situations where panels have a lack of space available or if power entering panel exceeds the capacity of the Standard Configuration (480 VAC, 2400 Amperes), alternate metering solutions that meet the requirements of standard configuration will be considered as follows:

1. Split Core Flexible CTs are encapsulated in silicone rubber allowing for movement when placing in a panel with minimal space. The CT’s are available in both round and rectangular shapes.

2. Flexible Rope CTs have two parts, the flexible coil and compact power and energy meter. The flexible coil is shaped like a rope and fits in extremely tight spaces.

The flexible coil is not a self-contained metering unit. The flexible coil is hard-wired into the power and energy meter where it transmits the data to the DAS via a Modhopper Transceiver.

B. Electric meters have higher failure rates when installed in medium and high voltage transfromers and…