Attachment I - CSTO Advanced Metering Infrastructure .pdf

Base San Juan Hurricane Rebuild West and Central Locations

Project No. 10878158 USCG Base San Juan, PR

Attachment I CSTO – Advanced Metering Infrastructure

Mission Support Business Model

Configuration

Standard

Technical Order

Advanced Metering Infrastructure

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

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

03 JUL 2018

Subject: ADVANCED METERING INFRASTRUCTURE CSTO

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 end points. 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 Configuration Control Board.

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.

5. ENVIRONMENTAL ASPECT AND IMPACT CONSIDERATIONS.

a. The general policies contained in this technical order are categorically excluded under current USCG categorical exclusion #33 from further environmental analysis, in accordance with the National Environmental Policy Act Implementing Procedures and Policy for Considering Environmental Impacts, COMDTINST M16475.1 (series).

b. All future specific actions resulting from the general policies in this technical order must be individually evaluated for compliance with the National Environmental Policy Act (NEPA), Council on Environmental Quality NEPA regulations at 40 CFR Parts 1500-1508, DHS and Coast Guard NEPA policy, and compliance with all other environmental mandates.

Subj: Advanced Metering Infrastructure CSTO

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 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

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

John Regan Design Section Chief FDCC Project Execution Branch

Paul Miller Asset Line Analyst Jacobs

John Harsche Resource Efficiency Manager Tetra Tech, Inc.

http://cglink.uscg.mil/AMI

Subj: Advanced Metering Infrastructure CSTO

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.

T. WADE GESELE

Captain, U.S. Coast Guard 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

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 of 2005 (EPAct) and the Energy Independence and Security Act of 2007

(EISA 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 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

Branch (SILC – ESD-Energy), 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 shows the wider context of those relationships, while Table 1-3 shows the roles and responsibilities as they pertain to this CSTO.

AMI Program Responsibilities

SILC ESD

Energy Branch

SILC BOD CG-6 FE/EPO CG-46

Design Engineer

(FD&CC,

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 thru

AMI

Develops/ or Includes

Plans and Specifications for AMI Installations

Support AMI Hardware

Requirements

Prioritizes AMI Projects

Perform Energy Audits

Thru REMs

Support AMI Data

Management

Support

EDMS

Client

Perform AMI Maintenance

Perform Energy Analysis

Manage

Network at Site

Perform Energy

Analysis

Figure 1: AMI Program Relationships

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 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 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 Initiative (AMI) Project in 2012. During this initial rollout of the AMI, equipment from Obvius LLC., an energy solutions provider, was selected as the standard configuration for Data Acquisition Servers (DAS) and Transceivers. Over 1960 advanced electrical meters were installed in Coast Guard buildings at appropriate assets – buildings equal or greater than 5000 SF, buildings with high energy use, select family housing and tactical assets (shore ties).

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 S

IL

C

B O

D

S

IL

C

E S

D

E N

E R

G Y

M

P L

P L

C

IV

W A

L

D E

S

IG

N E

N G

IN

E

R

F

E

P

-4 o n tr a c to r

C

-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, and equipment necessary for optimization of building operations, selected family housing communities, and connections for tactical assets. Key federal guidance includes the Energy Policy Act of 2005 - Section 103, EISA 2007, Executive Order 13963 and the Federal Energy Management Program for Metering Best Practices.

DHS 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

(when it is cost effective). 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 O&M 3.0. Additionally the guidance calls for a concentrated effort to meter building energy consumption on a sub-building level though sub-metering for certain building types, for example data centers, as energy use has increased significantly over the years in these facilities. Water meters should be installed based on water use and flow at the whole building level. The water meters must comply with all federal requirements 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 shall be installed.

Figure 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: Facility Qualification Decision Matrix

Table 2-1: Advanced Energy (Electricity and Natural Gas / Propane) Meter Thresholds* a c il it y F u n c ti n e a l

P ro p e rt y U s e o r

C a te g o ry C o d iz

(G re a te r th a n o r

E q u a l)

All Other Land ** 80 5,000

Communications Systems 72 5,000

Dormitories/Barracks 31 5,000

Hospital 21 5,000

Housing 30 5,000

Industrial*** 50 5,000

Laboratories 74 5,000

Museum 28 5,000

Start Sold or razed within the next five years?

High usage

(Data

Center, HVAC, etc.)

Exceed thresh olds per

AMI

CSTO

Operati onal

Security

Exclusio n ?

Respon sible for

Utility

Bills?

No

Adva nced

Meter

Will

Operatio ns Benefit from

Meter?

Facility

Modific ation

Allowed

YES

YES

NO

N

O

YE

S

YE

S

N

O

YE

S

NO

Prioritiz e

Meterin g

Projects

N

YES

NO

Y

NO

c il it y F u n c ti n a l

P ro p e rt y U s e o r

C a te g o ry C o d iz

(G re a te r th a n o r

E q u l)

Aids To Navigation(ATON) and Traffic Aids 73 5,000

Office Building Locations 10 5,000

Other Institutional Uses *** 29 5,000

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

Pier/Wharf (master meter for all shore ties) 151-20 Other Vessels

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 CATCODES 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

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 ($200K or greater).

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

3. Shore Ties.

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

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

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

7. All individual buildings 10,000 square feet or above.

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

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

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

Water Metering

1. New Constructions and Major Renovations ($200K 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, vehicle wash stations, industrial facilities, hospitals, prisons, water-intensive laboratories, and large landscape systems.

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

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

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

3 TECHNICAL REQUIREMENTS

3.1 Organization

The technical requirements section delineates the equipment and software considerations of the

Advanced Metering Initiative 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 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 3.2.1through 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 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 (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 (kW) and consumption (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 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. The meter shall report serially over an RS-485 network using the Modbus (RTU) protocol.

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

E. The flow meter shall accept an input power of 24 VDC and output a 4-20 mA signal of the flow rate along with a pulse output.

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

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

H. 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.

I. Calibration system shall be NIST traceable.

J. 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.

K. 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 most current federal mandates for potable and process water use reporting requirements.

B. Water meters shall be a Positive Displacement Meter type.

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

D. The water meters shall support capture of variables at the interval defined in Section 3.3.3.

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

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

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

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

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

J. The water meters shall support a Maximum Operating Pressure of 150 psi.

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

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

B. The water meters shall support capture of variables at the interval defined in Section 3.3.3.

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

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

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

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

G. BTU System shall:

1. RTD meets IEC751 Class B.

2. Electrical Inputs meet RS-485.

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

I. Tee shall be constructed from cast bronze.

J. Hot liquid sensor shall have continuous operating temperature of 40° to 260°F [4° to 125°C].

K. Chilled liquid sensor shall have continuous operating temperature of -4° to 140°F [-20° to 60°C].

L. 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 500mS. Resulting frequency range is 0.01 Hz min. to 100 Hz max.

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

M. Standard flow measurement range shall be 0.6-6 MPS [1.97 to 19.69 FPS].

N. Low flow measurement range shall be 0.09-2.5 MPS [.295 to 8.2 FPS].

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

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

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

R. 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'' NPT.

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 10ft/s 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 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

A. The DAS shall be an Obvius AcquiSuite® Model A8812. No substitutions shall be permitted. See Appendix D.

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 V - Min/Max/Ave/Instantaneous.

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

3. Pulse - Consumption, Rate.

4. Resistance - Min/Max/Ave/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 LAN connections (static IP or DHCP), 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 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

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 1000mW 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 PC 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 LED's 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 at a maximum range of 3000 feet indoors, without line-of-sight and up to 14 miles with line of sight.

N. The transceiver must utilize 256 bit AES encryption 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, 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

3.3.1.1 Introduction

As data is collected, it shall be communicated to a common repository for storage and analysis similar to that shown in Figure 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 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 Initiative (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) are described in Section 3.3.2 Key Data Fields.

Figure 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 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

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

Voltage, Line to Neutral Volts

Current Amps

Variable Unit

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 cuft/hour

Gas Ave Rate cuft/hour

Gas Instantaneous Rate cuft/hour

Gas Min Rate cuft/hour

Gas Max cuft/hour

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. Upon receipt of the information, DAS, meter and transceiver device names will be provided by the Coast Guard to the contractor.

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 and transceivers 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. DASs, 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 in accordance with IEEE 1100-2005

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.

Water

A. Pulse Initiators may be used on existing Utility-owned water meters with prior written consent and assistance by the Local Utility Account Representative. The Contractor shall be responsible for coordinating access to local utility owned assets and notify COR.

Gas

A. Installation of gas piping shall be in accordance with ANSI B31.8

B. When connecting to existing steel piping systems, provision shall be made to ensure that the integrity of the cathodic protection is not compromised.

C. Pulse Initiators may be used on existing Utility-owned gas meters with prior written consent and assistance by the Local Utility Account Representative. The Contractor shall be responsible for coordinating access to local utility owned assets and notify COR.

4.1.2 Data Acquisition Servers (DAS)

A. The DAS shall have full administrative capabilities enabled to the unit’s metering lead for initial configuration and for ongoing use of console level metrics.

B. For configuration of the DAS: (refer to DAS Manual) http://www.obvius.com

C. The check box to allow remote configuration shall be checked on the “LogFileData, Setup/Upload” page (See DAS Manual.)

D. A cellular modem shall be installed as part of the DAS installation or add to existing DAS. Contractor or unit shall notify USCG SILC Energy Branch 30 days in advance to request cellular ISP information for connectivity.

1. The DAS shall be connected to cellular modem compatible with the USCG Cellular and Internet Service Provider (ISP) service.

2. If Cellular Service in not available, The DAS shall be configured to dial out land line or POTS (Plain Old Telephone Service) using the ISP phone number and access.

E. The Coast Guard unit shall notify SILC Energy Branch it is ready for the interface to the selected EDMS.

F. The metering contractor shall verify the new DAS is active on the EDMS website.

4.1.3 Transceivers

A. Installation technicians shall ensure unique address for each transceiver, settable via dipswitches on each device, in order to mitigate conflicts and ease troubleshooting efforts. Refer to Appendix F - AMI Equipment Naming Convention Document.

B. Installation shall comply with NFPA 70 and NEC.

C. Equipment, installation, and wiring shall comply with industry specifications, standards and local codes for performance, reliability, and compatibility.

D. Hardwired installations shall use shielded twisted-pair 2 conductor cable compatible with Belden 1120A.

E. Installation technicians shall locate transceivers in suitable areas-side or rear facades of buildings if possible, free from large metal plates or sources of radio signals, electrical panels, obstructed locations, thick concrete walls, or areas of high electrical noise.

F. Installation technicians shall verify with local facilities personnel the presence of cellular repeaters or Wi-Fi networks.

G. Install transceivers as per manufacturer's recommendations and best practices, in order to maximize strength of wireless communication. If the wireless connection between transceivers is weak or intermittent, additional relay transceiver(s) or external antennas shall be installed to facilitate reliable communication.

H. Transceivers shall be mounted a minimum of 10 feet away from other radio devices, including other transceivers, cordless phones, and Wi-Fi access points. This minimum is based on typical transmitting power—greater distance may be desired from sources of greater power such as cell phone towers and communication transmitters.

I. Transceivers are powered by a 120v wall mounted transformer, and thus shall be mounted close to an available receptacle securely to a wall.

http://www.obvius.