GE Industrial Solutions EPM4500 User Manual

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GE Energy

Industrial Solutions

EPM 4500

SUB METER

Instruction Manual

Manual P/N: 1601-0157-A9 Manual Order Code: GEK-106555I

GE Energy Industrial Solutions

41 Woodford Avenue

Plainville, CT 06062

Internet: http://www.geindustrial.com

Table of Contents

1: OVERVIEW GETTING STARTED ........................................................................................................................... 1-1

ESCRIPTION ........................................................................................................................ 1-1

APPLICATIONS ................................................................................................................................... 1-2

TAND-ALONE METER ........................................................................................................ 1-2

ETERING SYSTEM .............................................................................................................. 1-2

NTERIOR VIEW ....................................................................................................................1-3

AUTIONS AND WARNINGS ............................................................................................... 1-3

ROTECTIVE CONDUCTOR TERMINAL ............................................................................... 1-4

REVENTIVE MAINTENANCE ............................................................................................... 1-4

SPECIFICATIONS ............................................................................................................................... 1-5

ONITORING ........................................................................................................................ 1-5

OWER SUPPLY ................................................................................................................... 1-5

ETERING ............................................................................................................................. 1-5

NPUTS .................................................................................................................................. 1-6

OMMUNICATIONS .............................................................................................................. 1-6

HYSICAL .............................................................................................................................. 1-6

YPE TESTS AND APPROVALS ............................................................................................ 1-6

ORDERING ........................................................................................................................................... 1-8

EPM4500 R EPM4500 C

PTIONS ...............................................................................................................................1-8

URRENT TRANSFORMERS (0.1 A SECONDARY) .............................................................1-9

RANSPONDER MODELS .....................................................................................................1-9

ULSE INPUTS ...................................................................................................................... 1-9

ESIDENTIAL .................................................................................................... 1-8

OMMERCIAL ................................................................................................... 1-8

2: INSTALLATION GETTING READY ................................................................................................................................ 2-1

ETERMINATION OF METERING SYSTEM REQUIREMENTS .............................................. 2-1

HASE ASSOCIATION ........................................................................................................... 2-1

WIRING ................................................................................................................................................. 2-2

VERVIEW OF METER WIRING .......................................................................................... 2-2

IRING OVERVIEW ............................................................................................................. 2-2

HREE-PHASE FOUR-WIRE WYE WIRING ....................................................................... 2-3

INGLE-PHASE, THREE-WIRE 120 V WIRING ............................................................... 2-6

HREE-PHASE, THREE-WIRE DELTA WIRING ................................................................. 2-9

INGLE-PHASE, THREE-WIRE WIRING ............................................................................. 2-12

INSTALLATION OF METER, MCI BOARD, AND CTS .............................................................2-15

ROCEDURE .......................................................................................................................... 2-15

INSTALLING THE SCAN TRANSPONDER ................................................................................. 2-18

ROCEDURE .......................................................................................................................... 2-18

3: USING THE METER MENU NAVIGATION ........................................................................................................................ 3-1

SER INTERFACE ..................................................................................................................3-1

CT MULTIPLIER TABLE .................................................................................................................... 3-4

ULTIPLIERS .................................................................................................................. 3-4

CT M

VERIFYING METER FUNCTIONALITY ......................................................................................... 3-5

VERVIEW ............................................................................................................................ 3-5

EPM 4500 SUB METER – INSTRUCTION MANUAL TOCTOC–I

VERIFYING VOLTAGE ...........................................................................................................3-5

ERIFYING KWH READING ................................................................................................. 3-5

ERIFYING CURRENT AND ENERGY ................................................................................... 3-6

RESETTING THE DEMAND VALUES ........................................................................................... 3-7

ROCEDURE ..........................................................................................................................3-7

4: COMMUNICATIONS MODBUS COMMUNICATIONS ..................................................................................................... 4-1

RS485 W RS232 W

ODBUS COMMANDS ......................................................................................................... 4-2

IXED MODBUS VALUES ..................................................................................................... 4-2

ODBUS DATA REGISTER (R4 TYPE) GROUPS ................................................................ 4-3

NSTANTANEOUS DATA ITEMS ............................................................................................4-3

I 32-

IRING FOR MODBUS ......................................................................................... 4-1

IRING FOR MODBUS ......................................................................................... 4-2

BIT LONG AND FLOAT DATA FORMATS ..................................................................... 4-4

MODBUS ACTIVATION .................................................................................................................... 4-5

VERVIEW ............................................................................................................................ 4-5

ONFIGURING A NEW HYPERTERMINAL SESSION .......................................................... 4-5

ONFIRMING CONNECTION TO THE EPM4500 .............................................................4-6

OGGING INTO THE METER ................................................................................................ 4-6

CTIVATING MODBUS COMMUNICATIONS ....................................................................... 4-7

HANGING MODBUS SETTINGS ......................................................................................... 4-8

OGGING OUT ...................................................................................................................... 4-8

ISABLING MODBUS COMMUNICATIONS ......................................................................... 4-8

MODBUS MEMORY MAP ................................................................................................................ 4-9

EMORY MAP ......................................................................................................................4-9

5: MISCELLANEOUS REVISION HISTORY .......................................................................................................................... 5-1

ELEASE DATES ...................................................................................................................5-1

HANGES TO THE MANUAL ................................................................................................ 5-2

WARRANTY ......................................................................................................................................... 5-4

NERGY WARRANTY ..................................................................................................... 5-4

GE E

TOCTOC–II EPM 4500 SUB METER – INSTRUCTION MANUAL

GE Energy

Industrial Solutions

709710A1.CDR

1.1 Getting Started

EPM4500 Sub Meter

Chapter 1: Overview

Overview

1.1.1 Description

Thank you for purchasing the GE Energy EPM4500 24-point sub-meter to monitor energy for your residential, commercial, or industrial applications. At GE Energy, we pride ourselves by providing our customers with best-in-class products, which have been carefully selected by GE to best serve your solution needs.

The EPM4500 is sold in KWh or Demand meter versions and is available for 120/208V and 277/480V applications. An integrated liquid crystal display (LCD) is standard on all versions, providing local access to real-time and historical data. The meter provides two standard communication modes: power line communications (PLC), which utilizes existing AC power lines as the communication medium, eliminating dedicated wiring, and Modbus (RS232, RS485, and modem).

The EPM4500 is packaged with either solid or split-core CTs in various amperages to suit both new construction and retrofit applications.

Note

The EPM4500 is primarily used for commercial and industrial applications and is available in voltages ranging from 120 to 600 V in both wye and delta forms. The following installation instructions are applicable to the EPM4500 meter only.

EPM 4500 SUB METER – INSTRUCTION MANUAL 1–1

APPLICATIONS CHAPTER 1: OVERVIEW

1.2 Applications

1.2.1 Stand-Alone Meter

The GE Energy EPM4500 can be installed as a stand-alone device that is locally accessed via the LCD or remotely accessed via modem. A modem can be installed in each meter allowing the meter(s) to be read remotely.

1.2.2 Metering System

The GE Energy EPM4500 family of meters are ideally designed to comprise a metering system within a residential/commercial building or industrial site. This metering system can measure electrical usage for each tenant, cost center, or common area space and communicate this information over the building's power wires or dedicated communication wiring (RS485). A metering system is comprised of two or more EPM4500 meters and at least one communication transponder (see figure below). The transponder collects metering data from multiple meters via AC power lines. For larger sites, additional transponders may be required. Multiple transponders can communicate via a data link network using RS485 or via a wireless network.

The metering data can be accessed from the transponder or network of transponders using a telephone modem or local RS232 connection to a PC for data transfers.

709712A1.CDR

FIGURE 1–1: Overview of Scan Transponder Functionality

1–2 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 1: OVERVIEW APPLICATIONS

1.2.3 Interior View

The interior of the EPM4500 is shown below.

709711A1.CDR

FIGURE 1–2: Interior View of the EPM4500

Note

Where the and symbols are seen on the EPM4500 meter, the manual must be consulted to determine the nature of any potential hazard and/or actions to be taken.

1.2.4 Cautions and Warnings

• Do not install if the device is damaged. Inspect the housing for obvious defects

CAUTION

WARNING

such as cracks in the housing.

• If the device is installed or used in a manner not specified by accompanying documents, the protection of the device may be impaired.

• If the device functions abnormally, proceed with caution. The protection of the device may be impaired.

• Do not install the meter around combustible gas or gas vapor.

• Do not install the meter in an electrical service with current or voltage outside of the specified limit of the device.

• Do not operate the meter with the cover removed.

• To avoid electric shock, disconnect mains before replacing fuses!

• See instructions for connection diagram.

• Risk of electric shock. Beware of working around this meter when the voltage is live.

• For continued protection against fire, replace only with fuses of specified voltage and current rating.

EPM 4500 SUB METER – INSTRUCTION MANUAL 1–3

APPLICATIONS CHAPTER 1: OVERVIEW

1.2.5 Protective Conductor Terminal

Securely fasten one end of the earthing wire so that the screw cuts the paint on the back box. Securely fasten other end of the wire to a true earth ground connection. When earthing to the electrical conduit, use continuous pipes, bending when necessary instead of using couplers.

1.2.6 Preventive Maintenance

There are no necessary preventative maintenance or inspection.

A Toshiba CR2032 coin battery is used in each device and is intended to be good for decades before replacement. Return to manufacturer for replacement.

1–4 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 1: OVERVIEW SPECIFICATIONS

1.3 Specifications

1.3.1 Monitoring

DEMAND

Consumption and demand: .....................kW and kWh

Demand reset:.................................................allows local reset of peak demand register

INTERVAL DATA AND PEAK DEMAND

Commercial:......................................................15 minute block demand interval and peak demand with

date and time stamp

Residential:........................................................1 hour block demand interval

DATA LOGGER

Duration:.............................................................120 days with kW and kWh

Battery:................................................................internal battery maintains time and current interval

metering data during power outage only

1.3.2 Power Supply

1.3.3 Metering

CONTROL POWER

Input:....................................................................120 V phase A to neutral

277 V phase A to neutral 480 V phase to phase (internally powered through metered voltage; no external

source is required)

Frequency:.........................................................50 to 60 Hz

Operating power: ...........................................2 watts for 120 V

5 watts for 277 V and 480 V

Fuses:...................................................................1 - Buss fuse 250 V / 500 V 0.25 A / 0.125 A slow-acting

3 - Buss fuse 250 V /600 V 4.0 A fast-acting

MEASURED VALUES

Real time per phase:.....................................voltage, current, kW, kvar, kVA, power factor, frequency,

phase angle

Data logging:....................................................kWh, kW demand

METER ACCURACY

Accuracy: ...........................................................0.5 class accuracy

±0.5% unity and 50% power factor, 1 to 100% of full-

scale

Standards: .........................................................meets revenue certifiable ANSI C12.1 and C12.16

accuracy standards

LIQUID CRYSTAL DISPLAY (LCD)

Display size:.......................................................32-digit LCD, 16 digits in two rows

Data digit height:............................................0.31"

Consumption register: .................................6 digits

EPM 4500 SUB METER – INSTRUCTION MANUAL 1–5

SPECIFICATIONS CHAPTER 1: OVERVIEW

1.3.4 Inputs

AC CURRENT INPUTS

CT input:..............................................................50 to 800 A primary available

Secondary inputs: ..........................................0.1 A or 5 A

AC VOLTAGE INPUTS

Metered voltage:.............................................120/208 V wye, 277/480 V wye, or 600 V delta

at 50 to 60 Hz

Rated voltage:..................................................90 to 110%

PULSE INPUTS

Inputs:..................................................................up to 48 form-A pulse inputs logged in programmable

intervals also count during power outage

Minimum wire gauge:...................................20 AWG

Maximum wire length:.................................300 ft.

Maximum rate: ................................................5 transitions/second

Minimum pulse width:..................................100 ms

1.3.5 Communications

EPM4500 COMMUNICATIONS

Protocols:............................................................Power line communications (PLC)

RS485 Modbus (2-wire, half-duplex, isolated)

Ports: ....................................................................IEC front optical point-of-access (POA) port

1.3.6 Physical

ENVIRONMENT

Usage:..................................................................For indoor use only

Enclosure:...........................................................NEMA 1 rated

Temperature:....................................................–20°C to +60°C

Humidity:............................................................0 to 95% relative humidity (non-condensing)

Pollution degree:.............................................1

Maximum altitude:.........................................2000 m

DIMENSIONS

Meter enclosure:.............................................13.5"H × 8.5"W × 4.5"D

CT terminal board enclosure: 13.5"H × 8.5"W × 4.5"D

SHIPPING

Shipping weight:.............................................1 meter assembly 34 lbs. (total weight)

Shipping dimensions: ...................................2 enclosures, each 13.5"H × 8.5"W × 4.5"D

1.3.7 Type Tests and Approvals

TYPE TESTS

Transient/surge suppression: ANSI C37.90.1-1989

Installation category:....................................III. This product falls under Installation Category III

because of its distribution level, fixed installation and has

smaller transient overvoltages than an Installation

Category IV.

1–6 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 1: OVERVIEW SPECIFICATIONS

APPROVALS

ANSI: .....................................................................C12.1 and C12.16 accuracy

UL and CUL: ......................................................recognized under E204142

Industry Canada:............................................MC#AE-1148

EPM 4500 SUB METER – INSTRUCTION MANUAL 1–7

ORDERING

EPM 4500 SUB METER – INSTRUCTION MANUAL

1.4 Ordering

1.4.1 Enclosure

Step 1: Select Enclosure

Family Back Box Voltage Options Description

PL4500 BBA * * Back Box Assembly

1.4.2 EPM 4500 Residential

The EPM 4500 residential package is available in single-phase 120/208 V or 120/240 V connections. Residential use measures kWh only (no demand measurement).

Step 2: Select required meter head

Family Voltage Phase Wires Application Metering Points CTs Options Description

PL4500 * * * * * * *

CHAPTER 1: OVERVIEW

120V 120/208V 3 phase, 4 wire 208V 208V 3 phase 3 wire 240V 120/240V, 1 phase, 3 wire 277V 277/480V 3 phase, 4 wire 347V 347/600V 3 phase, 4 wire 480V 480V 3 phase 3 wire

E Future Communications Provision

Residential

120 3 4 R 120/208V 3 phase, 4 wire

03 3 Points

06 6 Points

09 9 Points

12 12 Points

24 24 Points

L 0.1 Amps Secondary Input H 5 Amps Secondary Input

P Pulse Data Input Module

240 1 3 R 120/240V, 1 phase, 3 wire

12 12 Points

24 24 Points

L 0.1 Amps Secondary Input H 5 Amps Secondary Input

P Pulse Data Input Module 277 277/480V 3 phase, 4 wire 347 347/600V 3 phase, 4 wire

3 4 R 24 L 24 points, 0.1 secondary CTs

1.4.3 EPM 4500 Commercial 4-Wire

The EPM 4500 commercial package is available in three-phase 120/208 V, 277/480 V, or 347/600 V connections (delta optional). Commercial use measures kWh and kW demand.

Family Voltage Phase Wires Application Metering Points CTs Options Description

PL4500 * * * * * * *

120 120/208V 3 Phase 277 277/480V 3 Phase 347 347/600V 3 Phase

1–8

Commercial 4-Wire

3 4 C 3 Phase 4 wire Commercial

06 6 Points 08 8 Points

L 0.1 Amps Secondary Input H 5 Amps Secondary Input

P Pulse Data Input Module

M Modem

RS RS485 Connection

MOD Modbus Communication

EPM 4500 SUB METER – INSTRUCTION MANUAL

1.4.4 EPM 4500 Commercial 3-Wire

Commercial 3-Wire

Family Voltage Phase Wires Application Metering Points CTs Options Description

PL4500 * * * * * * *

208 208V 3 phase 3 wire 480 480V 3 phase 3 wire

3 3 C 12 12 points

1.4.5 Current Transformers (0.1 A Secondary)

CTs

Type Description Cat. No.

CT-50 (50/0.1A) PLSUBCTSL050

Solid Core - 0.1 A Secondary

Solid Core - Canadian CT-2/5DARL (200A/5A) PLSUBCTSL201CDN

Split Core - 0.1 A Secondary

CT-1 (100/0.1A) PLSUBCTSL101 CT-2 (200/0.1A) PLSUBCTSL201 CT-4 (400/0.1A) PLSUBCTSL401

CTSP-50 (50/0.1A) PLSUBCTSP050 CTSP-1 (100/0.1A) PLSUBCTSP101 CTSP-2 (200/0.1A) PLSUBCTSP201 CTSP-4 (400/0.1A) PLSUBCTSP401 CTSP-8 (800/0.1A) PLSUBCTSP801 CTSP-12 (1200/0.1A) PLSUBCTSP1201 CTSP-20 (2000/0.1A) PLSUBCTSP2001 CTSP-30 (3000/0.1A) PLSUBCTSP3001 CTSP-40 (4000/0.1A) PLSUBCTSP4001

ORDERINGCHAPTER 1: OVERVIEW

L 0.1 Amps Secondary Input

P Pulse Data Module M Modem RS RS485 Connection MOD Modbus Communication

1.4.6 Transponder Models

To order: Select Back Box, then select transponder model with options.

1. Order Back Box

Description Cat. No.

120V service back box TRANS BBA 120V 277V service back box TRANS BBA 277V 347V service back box TRANS BBA 347V

1.4.7 Pulse Inputs

The order codes for the pulse inputs are indicated below.

Cat. No.

PL4500PULSINA PL4500PULSINB PL4500PULSINC PL4500PULSIND

For additional information on pulse inputs, please contact GE Energy.

2. Order Transponder Model with options

Description Cat. No.

120/208V with modem TRANS120M 120/208V with RS485 and RS2332 connections TRANS120RS 277/480V with modem TRANS277M 277/480V with RS485 and RS232 connections TRANS277RS 347/600V with modem TRANS347M 347/600V with RS485 and RS 232 connections TRANS347RS

1–9

ORDERING CHAPTER 1: OVERVIEW

1–10 EPM 4500 SUB METER – INSTRUCTION MANUAL

GE Energy

Industrial Solutions

709710A1.CDR

2.1 Getting Ready

EPM4500 Sub Meter

Chapter 2: Installation

Installation

2.1.1 Determination of Metering System Requirements

Determine if the application is for a metering system or for a stand-alone meter. If the application is for a stand-alone meter, please read Overview of Meter Wiring on page 2–2. If the application is for a metering system, then also read Installing the Scan Transponder on page 2–18.

2.1.2 Phase Association

As shown in Table 2–1: Wiring Diagram / Model Reference on page 2–3, there are four wiring types for the EPM4500 meter. Each wiring type has a specific phase association table to ensure that current transformers are in-phase with the reference voltage. These phase association tables must be followed for the meter to function properly with the chosen wiring type.

The phase association of the current transformers must be followed or meter will not be installed correctly.

EPM 4500 SUB METER – INSTRUCTION MANUAL 2–1

WIRING CHAPTER 2: INSTALLATION

2.2 Wiring

2.2.1 Overview of Meter Wiring

Although this document treats the installation and certification stages separately, this does not imply that the recommended procedure is to install the entire system at once and then proceed to certification.

The recommended procedure is to install and certify the system in stages. By doing this, systematic error can be corrected before it propagates through the entire installation. To follow the recommended procedure, divide the job up into manageable stages and install and certify at each stage before proceeding to the installation of the next stage.

For the purposes of this discussion, the colors black, red and blue have been chosen to distinguish among the three phases of a three-phase network. White is the designated color of neutral and green is the color of earth ground. Please substitute the correct color according to local electrical code. For a two-phase installation, ignore the third phase (the blue phase in the following description).

Failure to follow the proper procedures and reference the correct wiring diagram can result in damage to the equipment and/or physical harm.

709714A1.CDR

FIGURE 2–1: Vertical Mounting Option

2.2.2 Wiring Overview

Review the following wiring types and select the one that matches your installation requirements and part number using the following table.

2–2 EPM 4500 SUB METER – INSTRUCTION MANUAL

Table 2–1: Wiring Diagram / Model Reference

Three-Phase Four-Wire Wye Wiring on page 2–3

Single-Phase, Three-Wire 120 V Wiring on page 2–6

Three-Phase, Three-Wire Delta Wiring on page 2–9

Single-Phase, Three-Wire Wiring on page 2–12

2.2.3 Three-Phase Four-Wire Wye Wiring

The phase association and polarity of the current transformers must be followed or the meter will not be correctly installed.

1. Current transformers must be in-phase with the reference voltage. The MCI board runs in an A-B-C phase rotation (see table below) and each of the three CT connections repeat an A-B-C order. For example, a current transformer installed in-phase with reference voltage A must be installed on CT1, CT4, CT7, etc. Current transformers installed in-phase with reference voltage B must be installed on CT2, CT5, CT8, etc. Likewise, current transformers installed in-phase with reference voltage C must be installed on CT3, CT6, CT9, etc.

WIRINGCHAPTER 2: INSTALLATION

Section

2. For the “C” or commercial 3-phase/4-wire model, each A-B-C combination is a single meter point (see the following table for full listing). That is,

3. – Meter 1 (M#1) is CT1, CT2, and CT3

– Meter 2 (M#2) is CT4, CT5, and CT6 – Repeated for M#3 to M#8

4. After completing all current transformer terminations, connect four (4) current connectors and then remove the twenty-four (24) shorting links.

5. Follow all local codes for installation requirements; e.g. conduit, fused disconnect, distance, and wiring.

6. Installation of “L” (0.1 A inputs) and “H” (CL10 or 5A inputs) are the same. For 6 point models, use meter points M#1 to M#6; M#7 and M#8 are not functional.

If breakers are energized, shorting links must be installed before:

1. disconnecting the CT headers

2. replacing or installing meter heads on the panel.

Bodily injury may result if shorting links are not installed!

EPM 4500 SUB METER – INSTRUCTION MANUAL

2-3

WIRING CHAPTER 2: INSTALLATION

Table 2–2: Phase Association Table for 3-Phase 4-Wire Wye Wiring

MeterMCI Board CT Voltage

Phase

2B 14B

3C 15C

5B 17B

6C 18C

8B 20B

9C 21C

10 A

11 B 23 B

12 C 24 C

MeterMCI Board CT Voltage

Phase

13 A

16 A

19 A

22 A

2–4 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 2: INSTALLATION WIRING

Power

Load

Phase A (ØA)

Source

Neutral

BK/RD/BL

Dot

Dot or H1 should point

source.

towards the line or

WHITE

LINE SOURCE

Diagram 3. CT Phasing.

CT Header

CT4

CT2

meterhead

Connect CT Header to

To CT2

To CT4

CT Header

To CT1

To CT3

Power Header

Beads

Ferrite

inside tenant breaker panel.

CT3

Diagram 1. Current Transformers installed

CT1

347/600V

277/480V

120/208V

ØC

MC-5

NA NB

IC NC N

ØAØB ØCIA

Meter #2

ØB

Load

Reference Voltage

15A Fast Acting Only

Service Disconnect Switch

RECOMMENDED:

Load

Phase B (ØB)

Phase C (ØC)

Tenant Breaker Panel

Conduit

installed correctly. See Diagram 1 for CT installation

CRITICAL - Current Transformers (CT) must be

and Table 1 for Phase Association relationships.

for each meter point. See Diagram 3 for CT polarity

Meter #1

ØA

BK RD BL WH

ØC

ØA

ØB

Meter #1Meter #2Meter #3

Shorting Links

Installation Notes for details.

Diagram 2. Shorting Links. See

MCI INTERFACE

Meter #5

709701A3.CDR

Meter #4

TENANT BREAKER PANEL

Meter #8

Meter #7

Meter #6

FIGURE 2–2: 3-Phase 4-Wire Wye Wiring

EPM 4500 SUB METER – INSTRUCTION MANUAL 2–5

WIRING

CHAPTER 2: INSTALLATION

2.2.4 Single-Phase, Three-Wire 120 V Wiring

The phase association and polarity of the current transformers must be followed or the meter will not be correctly installed.

2. For the “R” or residential 3-phase/3-wire model, each A-B, C-A, and B-C combination is a single meter point (see the table below for full listing). That is,

3. – Meter 1 (M#1) is CT1 and CT2

– Meter 2 (M#2) is CT3 and CT4 – Repeated for M#3 to M#12

4. After completing all current transformer terminations, connect four (4) current connectors and then remove the twenty-four (24) shorting links.

5. Follow all local codes for installation requirements; e.g. conduit, fused disconnect, distance, and wiring.

6. Installation of “L” (0.1 A inputs) and “H” (CL10 or 5 A inputs) are the same. For the 3, 6 and 9 point models, use meter points M#1 to M#3, M#1 to M#6, and M#1 to M#9, respectively. M#4 to M#12, M#7 to M#12, and M#10 to M#12 are not functional for the 3, 6 and 9 point models, respectively.

If breakers are energized, shorting links must be installed before:

1. disconnecting the CT headers

2. replacing or installing meter heads on the panel.

Bodily injury may result if shorting links are not installed!

2-6

EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 2: INSTALLATION WIRING

Table 2–3: Phase Association Table for 1-Phase 3-Wire 120 V Wiring

Meter MCI Board CT Voltage

Phase

2B 14B

4A 16A

6C 18C

8B 20B

10 A 22 A

11 B

12 C 24 C

Meter MCI Board CT Voltage

Phase

13 A

15 C

17 B

19 A

21 C

23 B

EPM 4500 SUB METER – INSTRUCTION MANUAL 2–7

WIRING CHAPTER 2: INSTALLATION

Power

Load

Phase A (ØA)

Source

Neutral

BK/RD/BL

Dot

Dot or H1 should point

source.

towards the line or

WHITE

LINE SOURCE

Diagram 3. CT Phasing.

CT Header

CT4

CT2

meterhead

Connect CT Header to

To CT2

To CT4

CT Header

Power Header

Beads

Ferrite

CT3

CT1

347/600V

277/480V

120/208V

MC-5

NA NB

IC NC

ØAØB

ØCIA

To C T 1

Diagram 1. Current Transformers installed

inside tenant breaker panel.

Meter #3

ØB

To C T 3

BLRD

ØC

Meter #2

ØA

RD BL

Reference Voltage

ØC

Load

15A Fast Acting Only

RECOMMENDED:

Service Disconnect Switch

Load

Phase B (ØB)

Phase C (ØC)

Tenant Breaker Panel

Conduit

CRITICAL - Current Transformers (CT) must be

installed correctly. See Diagram 1 for CT installation

and Table 1 for Phase Association relationships.

for each meter point. See Diagram 3 for CT polarity

Meter #1

ØA

ØB

RD BL

Meter #5Meter #6

709722A1.CDR

Meter #4

TENANT BREAKER PANEL

Meter #11Meter #12 Mete r #10

Meter #9 Meter #8 Meter #7

Meter #2

Meter #1Meter #3

Shorting Links

Installation Notes for details.

Diagram 2. Shorting Links. See

MCI INTERFACE

FIGURE 2–3: 1-Phase 3-Wire 120 V Wiring (Network)

2–8 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 2: INSTALLATION WIRING

2.2.5 Three-Phase, Three-Wire Delta Wiring

The phase association and polarity of the current transformers must be followed or the meter will not be correctly installed.

1. Current transformers must be in-phase with the reference voltage. The MCI

board runs in an A-C phase rotation (see table below) and every two CT connections repeat an A-C order.

For example, a current transformer installed in-phase with reference voltage A must be installed on CT1, CT3, CT5, etc. Current transformers installed in-phase with reference voltage C must be installed on CT2, CT4, CT6, etc.

2. For the “C” or commercial 3-phase/3-wire model, each A-C combination is a

single meter point (see the table below for full listing). That is,

– Meter 1 (M#1) is CT1 and CT2 – Meter 2 (M#2) is CT3 and CT4 – Repeated for M#3 to M#12

3. After completing all current transformer terminations, connect four (4) current

connectors and then remove the twenty-four (24) shorting links.

4. Follow all local codes for installation requirements; e.g. conduit, fused

disconnect, distance, and wiring.

5. Installation of “L” (0.1 A inputs) and “H” (CL10 or 5 A inputs) are the same.

If breakers are energized, shorting links must be installed before:

1. disconnecting the CT headers

2. replacing or installing meter heads on the panel.

Bodily injury may result if shorting links are not installed!

EPM 4500 SUB METER – INSTRUCTION MANUAL 2–9

WIRING CHAPTER 2: INSTALLATION

Table 2–4: Phase Association Table for 3-Phase 3-Wire Delta Wiring

Meter MCI Board CT Voltage

Phase

2C 14C

4C 16C

6C 18C

8C 20C

10 C 22 C

11 A

12 C 24 C

Meter MCI Board CT Voltage

Phase

13 A

15 A

17 A

19 A

21 A

23 A

2–10 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 2: INSTALLATION WIRING

BK/RD/BL

Dot

Dot or H1 should point

source.

towards the line or

WHITE

LINE SOURCE

Diagram 3. CT Phasing.

CT Header

CT4

CT2

meterhead

Connect CT Header to

To CT2

To CT4

CT Header

To CT1

To CT3

Power Header

Beads

Ferrite

inside tenant breaker panel.

Diagram 1. Current Transformers installed

CT3

CT1

347/600V

NA NB

277/480V

120/208V

IC NC N

ØAØB ØCIA

Meter #2

ØA

ØC

RECOMMENDED:

Conduit

Load

Phase A (ØA)

Phase B (ØB)

Phase C (ØC)

Tenant Breaker Panel

POWER

SOURCE

MC-5

UNGROUNDED

GROUNDED OR

NOTE: CORNER CAN BE

15A Fast Acting Only

Fused Disconnect

CRITICAL - Current Transformers (CT) must be

installed correctly. See Diagram 1 for CT installation

and Table 2-5 for Phase Association relationships.

for each meter point. See Diagram 3 for CT polarity

Meter #1

ØC

ØA

BK BL

Meter#5

Meter#6

TENANT BREAKER PANEL

Meter#3Meter#4

Meter#2

Meter#1

MCI INTERFACE

Installation Notes for details.

Diagram 2. Shorting Links. See

709723A1.CDR

Shorting Links

TENANT BREAKER PANEL

Meter #11

Meter #12

Meter #10

Meter#7Meter#8Meter#9

FIGURE 2–4: 3-Phase 3-Wire Delta Wiring

EPM 4500 SUB METER – INSTRUCTION MANUAL 2–11

WIRING

CHAPTER 2: INSTALLATION

2.2.6 Single-Phase, Three-Wire Wiring

The line association and polarity of the current transformers must be followed or the meter will not be correctly installed.

1. Line sources Line 1 and Line 2 are fed through the current transformers (CTs). Line 1 points towards the ‘dot’ or H1 of the CT while Line 2 points away from the ‘dot’ or H1 of the CT. The MCI board runs CT terminals CT#1 to CT#24 with each terminal connected to Meter 1 (M#1) to Meter 24 (M#24). The number of CT terminal and meter connections is dependent on the number of suites available. For example:

– Meter 1 (M#1) connects to CT#1 – Meter 2 (M#2) connects to CT#2 – Repeated for M#3 to M#24

2. After completing all current transformer terminations, connect four (4) current connectors and then remove the twenty-four (24) shorting links.

3. Follow all local codes for installation requirements; e.g. conduit, fused disconnect, distance, and wiring.

6. Installation of “L” (0.1 A inputs) and “H” (CL10 or 5 A inputs) are the same. For 12, 18 and 24 point models, use meter points M#1 to M#12, M#1 to M#18, and M#1 to M#24, respectively.

If breakers are energized, shorting links must be installed before:

1. disconnecting the CT headers

2. replacing or installing meter heads on the panel.

Bodily injury may result if shorting links are not installed!

2-12

EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 2: INSTALLATION WIRING

Table 2–5: Line Association Table for 1-Phase 3-Wire Wiring

Meter MCI

Board CT

Reference Voltage

Line

Meter MCI

Board CT

Reference Voltage

Line

1 1 L#1(+) and L#2(–) 13 13 L#1(+) and L#2(–)

2 2 L#1(+) and L#2(–) 14 14 L#1(+) and L#2(–)

3 3 L#1(+) and L#2(–) 15 15 L#1(+) and L#2(–)

4 4 L#1(+) and L#2(–) 16 16 L#1(+) and L#2(–)

5 5 L#1(+) and L#2(–) 17 17 L#1(+) and L#2(–)

6 6 L#1(+) and L#2(–) 18 18 L#1(+) and L#2(–)

7 7 L#1(+) and L#2(–) 19 19 L#1(+) and L#2(–)

8 8 L#1(+) and L#2(–) 20 20 L#1(+) and L#2(–)

9 9 L#1(+) and L#2(–) 21 21 L#1(+) and L#2(–)

10 10 L#1(+) and L#2(–) 22 22 L#1(+) and L#2(–)

11 11 L#1(+) and L#2(–) 23 23 L#1(+) and L#2(–)

12 12 L#1(+) and L#2(–) 24 24 L#1(+) and L#2(–)

Note

In the above table:

• L#1(+) indicates that Line 1 points towards the ‘dot’ or H1 of the CT

• L#2(–) indicates that Line 2 points away from the ‘dot’ or H1 of the CT

EPM 4500 SUB METER – INSTRUCTION MANUAL 2–13

WIRING CHAPTER 2: INSTALLATION

Load

Source

Power

Line 1

BK/RD/BL

Dot

Dot or H1 should point

source.

towards the line or

WHITE

LINE SOURCE

Diagram 3. CT Phasing.

CT Header

CT4

CT2

meterhead

To CT2

To CT4

Connect CT Header to

CT Header

To CT1

To CT3

Power Header

Ferrite

Beads

CT3

CT1

inside tenant breaker panel.

Diagram 1. Current Transformers installed

NA NB

347/600V

277/480V

120/208V

IC NC N

ØAØB

ØCIA

Meter #2

MC-5

Load

15A Fast Acting Only

Fused Disconnect

RECOMMENDED:

Conduit

Neutral

Line 2

Tenant Breaker Panel

CRITICAL - Current Transformers (CT) must be

installed correctly. See Diagram 1 for CT installation

and Table 1 for Phase Association relationships.

for each meter point. See Diagram 3 for CT polarity

BK RD

Meter #1

Met er #12

Met er #11

TENANT BREAKER PANEL

Meter#8

Met er #10

Meter#7

Meter#9

Meter#6

Meter#5

Meter#4

Meter#3

Meter#2

Meter#1

MCI INTERFACE

Installation Notes for details.

Diagram 2. Shorting Links. See

Shor tin g L inks

709724A1.CDR

Meter #20

Met er #19

Met er #18

Met er #24

TENANT BREAKER PANEL

Met er #22

Met er #23

Meter #21

Met er #17

Met er #15

Meter #14

Meter #13

Met er #16

FIGURE 2–5: 1-Phase 3-Wire Wiring

2–14 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 2: INSTALLATION INSTALLATION OF METER, MCI BOARD, AND CTS

2.3 Installation of Meter, MCI Board, and CTs

2.3.1 Procedure

Note

The use of the following procedure is mandatory. Certification requires a visual inspection of the current transformers and the voltage taps on the incoming feeder phase wires.

Z Locate a section of wall to mount the EPM4500 back box and the

MCI board box. Keep in mind that the metal conduit must be mounted between the two boxes to allow the four large block connectors on the MCI board to connect to the meter head. The conduit is 2 inches long.

Z Determine how the back box and the MCI board box will be

oriented on the wall.

• Remove the square punch-outs from the side of the back box that will be interfacing with the MCI board box.

Z Mount the metal conduit to the side opening of the back box prior

to mounting the box to the wall to ease the spacing between boxes when mounting the MCI board box.

Z Mount the back box to the wall, or in the wall for flush mount

installations.

• Connect the breaker panel box to the back box of the meter with a metal conduit through which the 3 or 4 feeder phase voltage taps will be run.

• Make sure to use at least a ¾-inch diameter conduit to allow for all wires to pass easily.

Z Screw the corresponding opening on the MCI board box to the

conduit and mount the box to the wall.

Z Locate the incoming feeder phase (hot) wires at the top of the

breaker panel.

• Tape the incoming feeder wires according to phase with black, red and blue electrical tape for identification purposes.

Z Extend the CT wires with AWG #16 stranded with black, red and

blue jackets so as to be the correct length to pass through the conduit and reach the MCI board.

• Extend the white wire of each CT with a white wire, but place a black, red or blue electrical tape on the end of the extended wire to identify the correct neutral.

• Refer to these CT white wires with tape as white/black, white/red and white/blue respectively.

Refer to the Phase Association tables in Wiring on page 2–2 when wiring the MCI board. Failure to improperly observe proper phase association will result in incorrect metering data.

Z Remove the incoming feeder hot wires one at a time and place

each CT over the proper feeder wire.

EPM 4500 SUB METER – INSTRUCTION MANUAL 2–15

INSTALLATION OF METER, MCI BOARD, AND CTS CHAPTER 2: INSTALLATION

• Ensure that the colors of the CT leads correspond to the color of the tape on the phase feeder.

• Make certain that the white wire from the CT is closest to the line side of the feed, away from the top of the breaker panel.

• For split-core CTs, ensure that the X1 is toward the line side.

• Run the CT secondary wires through conduit to the back box of the meter.

Z Tap the feeder wires with AWG #12 stranded wire with black, red

and blue jackets taking care to match the color of the insulation of the #12 wires to correspond to the color of the tape on the feeder wire.

Z If the service is 4-wire, tap the neutral connection with a #12 AWG

stranded wire with a white jacket.

Z Run the current transformer wires black, white/black, red, white/

red and blue, white/blue to terminals CT-1 (I, N), CT-2 (I, N), CT-3 (I, N), etc. on the MCI board (see the following figure).

The shorting links MUST remain in place while wiring the CTs to the MCI board. Failure to do could result in severe injury and equipment damage.

Shorting links MUST BE in place when wiring CT leads to the MCI board.

White wire connects to "I" terminal Colored wire connects to "N" terminal

709715A1.CDR

FIGURE 2–6: Wiring of the MCI Board

Z Take the black, red, blue and white (if available) #12 AWG feeder

phase tap wires and run them to VA, VB, VC and N (if available) respectively (see the following figure).

2–16 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 2: INSTALLATION INSTALLATION OF METER, MCI BOARD, AND CTS

709716A1.CDR

FIGURE 2–7: Internal Fuse Block

Z Plug the fuse block into the meter head and hang the meter head

on the back box.

EPM 4500 SUB METER – INSTRUCTION MANUAL 2–17

INSTALLING THE SCAN TRANSPONDER CHAPTER 2: INSTALLATION

2.4 Installing the Scan Transponder

2.4.1 Procedure

If your application is for a metering system, use the following procedure to install the scan transponder.

Z Plan for the transponders.

• Determine the number of services in order to determine the number of transponders.

• Do not rely solely on the memory of the local engineers or of the existing drawings. Drawings may not have been properly updated to reflect as-built conditions and memories are not always accurate. Use these as guidelines and then perform a survey.

• Open electrical cabinets as necessary and locate every master meter from the utility.

• Make careful note of the voltages of the various transponders.

Z Determine the number of tenant spaces.

• In residential applications, this number should be fixed. Often apartments are laid out on a grid, such as by floor and by line. In this case, the number of meters is simply the number of floors times the number of lines. This information is needed before any meters are installed or entered into the transponders.

• Determine which service feeds each metering point. This information is vital to proper system operation. Without this information, a laborious process of trial and error is necessary to determine which transponder must be used for each meter. This will increase the cost of certification and commissioning of the system.

Z Determine the service size and type of meter for each metering

point.

• In residential applications, this is probably a constant amperage across the entire job (either 50 A or 100 A with Series 10 meters).

Z Determine the number of telephone lines required and ensure

the lines are installed before the installation of any metering equipment.

Z Determine the number of independent services.

• Typically there is one service per distribution transformer that feeds the property, unless distribution transformers have parallel secondaries, which is rare.

Z Determine the best location for each transponder.

• This is the closest point to the first point at which the feeders for the service branch out into sub-feeders. To find this point, follow the feeders from the secondary of the distribution transformer (or the service entrance if the transformer is off the property) and place the transponder at the last point before the feeder breaks into multiple feeders.

2–18 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 2: INSTALLATION INSTALLING THE SCAN TRANSPONDER

Z Determine which of the transponders should have a telephone

modem, and order a telephone line to terminate at that point . Do not proceed with the installation until the telephone line is installed.

Z After the telephone line is installed, install the scan transponder

with the modem next to the telephone line. Install all three phases and the neutral to the transponder (see Installation of Meter, MCI Board, and CTs on page 2–15 for details).

Z If there is more than one transponder, install the other

transponders and the interconnecting RS485 line, if required, which links all of the transponders (go directly to Installation of Meter, MCI Board, and CTs on page 2–15 if there is only one transponder in the system or if each transponder in the system has a modem and telephone line connection).

• An RS485 line is a pair of wires, AWG #20 or larger in diameter, which begins at one transponder where a terminator is placed.

• The RS485 line runs from transponder to transponder ending at the final transponder, where another terminator is placed.

•It is critically important that there should never be three RS485 pairs entering or leaving a transponder box.

• For the two transponders which have terminators, only one RS485 pair leaves each box.

• For the other transponders, if there are more than two, exactly two RS485 lines should leave the box: each line goes to another transponder in the daisy-chain. Only one modem should be installed in a data link system. If there are two or more modems in a data link system, the transponders will not communicate with each other.

• There may be no more than 32 transponders on a daisy-chain. If there are more than 32, special care must be taken, which is beyond the scope of these instructions.

Z If possible, run the RS485 lines in a conduit to protect them from

damage.

Z It is critically important to observe the polarity of the wires. The

RS485 data link uses a black and yellow color code. Match black to black and yellow to yellow; otherwise the data link will not work.

Z To test the data link, measure the DC voltage across the yellow to

black wire. This should measure between 0.1 and 0.3 V. If it is negative or outside of that range, re-check all of the transponder boxes according to the above specifications.

EPM 4500 SUB METER – INSTRUCTION MANUAL 2–19

INSTALLING THE SCAN TRANSPONDER CHAPTER 2: INSTALLATION

2–20 EPM 4500 SUB METER – INSTRUCTION MANUAL

GE Energy

Industrial Solutions

709710A1.CDR

Using the Meter

3.1 Menu Navigation

EPM4500 Sub Meter

Chapter 3: Using the Meter

3.1.1 User Interface

The following figure shows the EPM4500 user interface located on the front panel of the meter. It is easy to navigate the various sub-menus to read metering data, reset values and view configuration data.

Press and hold the “Display Scroll” button. After two seconds, the LCD will display the

REVERSE message. Two seconds later, the LCD will display FORWARD. Two seconds later,

a different sub-menu register heading as shown on the following page (the top row) in will be displayed in two-second intervals. Note that the EPM4500 defaults to the kWh register.

709719A1.CDR

FIGURE 3–1: EPM4500 User Interface

EPM 4500 SUB METER – INSTRUCTION MANUAL 3–1

MENU NAVIGATION CHAPTER 3: USING THE METER

Releasing the display scroll button at a given submenu heading will allow you to cycle through the registers listed under the selected submenu heading. Pressing and releasing the display button will advance to the next block of registers in the sub-menu.

To reverse scrolling direction at either the heading level or within a submenu, press and hold the display scroll button. When

REVERSE is displayed after two seconds, release the

display scroll button. You can now go backwards through the menu selections by pressing and releasing the display scroll button.

To go back to the forward scrolling option, follow the same procedure, except release the display scroll button when

FORWARD is displayed.

3–2 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 3: USING THE METER MENU NAVIGATION

Figure 3–2: EPM4500 Display Structure

EPM 4500 SUB METER – INSTRUCTION MANUAL 3–3

CT MULTIPLIER TABLE CHAPTER 3: USING THE METER

3.2 CT Multiplier Table

3.2.1 CT Multipliers

Note

The following table MUST BE used to verify the correct current readings, based on the rating of the CT installed.

Table 3–1: CT Multiplier Tables

For “L” or 0.1 A models For “H” or 5 A models

CT Size Multiplier CT Size Multiplier

50 A × 0.5 200 A × 40

100 A × 1 400 A × 80

200 A × 2

400 A × 4

800 A × 8

Note

The multiplier that corresponds with the CT rating MUST BE applied to the current reading shown on the display of the EPM4500 by multiplying that reading by the multiplier shown above. The multiplier MUST also be applied in the same manner when calculating kW and kWh. Fai

lure to use the appropriate multiplier wil

l result in an incorrect diagnosis of the

meter's functionality and incorrect revenue billing.

3–4 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 3: USING THE METER VERIFYING METER FUNCTIONALITY

3.3 Verifying Meter Functionality

3.3.1 Overview

Once you have familiarized yourself with the EPM4500 menu structure, it is critical to verify that the meter and CTs are properly installed.

Note

To correctly diagnose the meter, there must be loads on all three phases of the meter.

3.3.2 Verifying Voltage

Z Press and hold the Display Scroll button until the following menu

heading is displayed:

Phase Diagnostic Registers

Z Release the Display Scroll button.

• Scroll down by pressing and releasing the Display Scroll Button until one of the following sub-menus are displayed (examples shown for 120 V, 277 V, and 347 V, respectively):

Volts 125.3 A

124.0 B 124.7 C

Volts 348.5 A

347.1 B 347.7 C

Z Verify that phases A, B and C are displaying voltages; i.e., for a

120 V AC, the reading should be 117 V +10%/–15%.

Volts 276.3 A

277.0 B 277.7 C

3.3.3 Verifying kWh Reading

Z Press and hold the Display Scroll button until the following menu

heading is displayed:

kW Registers

Z Release the Display Scroll button. Scroll down by pressing and

releasing the Display Scroll button until the following sub-menu is displayed:

AllHrs kWH

1.046 M# 1

Z Verify that the kWh value increases as you view the LCD.

Z To view screens for Meters 2 to 8 (M#2 to M#8), repeat the above

steps.

EPM 4500 SUB METER – INSTRUCTION MANUAL 3–5

VERIFYING METER FUNCTIONALITY CHAPTER 3: USING THE METER

3.3.4 Verifying Current and Energy

Z Press and hold the Display Scroll button until the following menu

heading is displayed:

Phase Diagnostic Registers

Z Release the Display Scroll button.

Scroll down by pressing and releasing the Display Scroll button until the following submenu is displayed:

Phase 1 7.468 A

818.7 W 100.5 R

The A(mperage) reading in the display above will always be a positive number, even if the CT was incorrectly installed. Check the reading to see if it indicates the approximate expected current. Remember that this applies to Phase 1 only. If all the numbers on the multiplier screen were 1.00 and the current transformers are 100:0.1, your multiplier is 1 and the readings are the actual values. If the CTs are 200:0.1, multiply the current reading by 2.

The W(att) reading will also count forward as your view the LCD. A negative power reading is indicative of an incorrectly installed CT, or one that is cross-phased with the wrong voltage (phase) leg. The R(eactive) reading can be negative, depending on the nature of the load. Negative values indicate a capacitive load while positive values indicate an inductive load.

Z Scroll down by pressing and releasing the Display Scroll Button

until the following submenu is displayed:

Ph 1 935.4 VA

6.8° .875 PF

Under normal conditions the phase angle (x.x°) should be close to 0° and the power factor should be a number close to 1. Resistive loads will have a power factor close to 1, while inductive loads will typically reflect a power factor between 0.80 to 0.95, or even lower.

If the phase angle on the lower left is a number close to 180°, it indicates the CT was installed backwards, or 180° out-of-phase. If the number is close to 120°, at least two CTs have been cross-phased, and a similar number will appear in the phase angle data in Phase 2.

Note

To view screens for Phases 2 to 24, repeat above steps.

3–6 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 3: USING THE METER RESETTING THE DEMAND VALUES

3.4 Resetting the Demand Values

3.4.1 Procedure

Use the following procedure to reset the Demand registers to zero:

Z Press and hold the Demand Reset button.

• The LCD will initially display the

• The LCD will then display the

Dmdreset 1 20:00 06/14/2003

Z Keep the Demand Reset button depressed until the screen updates

and displays the current date and time. This signifies that the demand has been reset.

GE Copyright message.

Dmdreset event screen:

EPM 4500 SUB METER – INSTRUCTION MANUAL 3–7

RESETTING THE DEMAND VALUES CHAPTER 3: USING THE METER

3–8 EPM 4500 SUB METER – INSTRUCTION MANUAL

GE Energy

Industrial Solutions

EPM4500 Sub Meter

Chapter 4: Communications

709710A1.CDR

Communications

4.1 Modbus Communications

4.1.1 RS485 Wiring for Modbus

The wiring for Modbus communications for two-wire and four-wire RS485 is indicated below.

For two-wire RS-485:

Color Function DB-9 Pinout

Yellow RX (+) 2 Black TX (–) 8

For four-wire RS-485:

Color Function DB-9 Pinout

Yellow (A) RX (+) 2 Black (B) RX (–) 3 Green (Y) TX (+) 7 Red (Z) TX (–) 8

EPM 4500 SUB METER – INSTRUCTION MANUAL 4–1

MODBUS COMMUNICATIONS CHAPTER 4: COMMUNICATIONS

709725A1.CDR

FIGURE 4–1: RS-485 Serial Connections

Note

The EPM4500 optical port is disabled for units with 2-wire RS485 connections.

4.1.2 RS232 Wiring for Modbus

The wiring for Modbus communications for RS232 is indicated below.

Color Function DB-9 Pinout

Black TX 2 Red RX 3 Green GND 5

4.1.3 Modbus Commands

The EPM4500 is capable of acting as a remote slave unit to a Modbus master device via modem, RS232, RS485, or PLC. Up to 32 EPM4500 meters (or other RS485 devices) can be daisy-chained together on a single LAN.

The EPM4500 communicates at a default baud rate of 19200, with no parity and 1 stop bit. The default Modbus address is 100. Changes to the default baud rate or address can be accomplished through the configuration file upload.

The following Modbus commands are supported by the EPM4500:

• 03: Read R4 type register(s)

• 06: Write single register; address “0” is used as the broadcast address

• 16: Write multiple registers; address “0” is used as the broadcast address

4.1.4 Fixed Modbus Values

The EPM4500 provides fixed register values indicating the meter's serial number, the meter's version number, and the Modbus addresses.

4–2 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 4: COMMUNICATIONS MODBUS COMMUNICATIONS

4.1.5 Modbus Data Register (R4 Type) Groups

The EPM4500 has divided the supported register map (see following pages) into the following register groups for various fixed and dynamic data values:

•Setup Information

•Interval

• Average Interval Data

• Instantaneous Data

• Three-Phase Data

•Real Time Data

• Meter Configuration Data

The EPM4500 provides access to stored-interval data channels via Modbus command. The data items as defined in the following register map are based on default data channels that include the following 3-phase-totaled values (interval average) per meter:

• Real Power in kW

• Reactive Power in kvar

• Apparent Power in kVA

• Power Factor

Data is logged per the configurable time interval value. The default log interval is 15 minutes.

The Modbus master can request stored interval data by writing the interval date and time to the appropriate registers and by setting the data status register to 1. Upon the data ready flag (address 67) being written to 1, the interval data registers (addresses 100 to 107) are simultaneously updated with the appropriate values for the requested interval. The data ready flag returns a 0 for “data is ready”, or “2” for “invalid time interval requested.”

The EPM4500 also provides registers that constantly hold the oldest stored-interval (addresses 58 to 60) and most recent stored-interval time a to 63).

4.1.6 Instantaneous Data Items

The EPM4500 provides registers for per-phase instantaneous values (see below). Instantaneous register values are updated once per second.

•Frequency

• Total Harmonic Distortion (% for volts)

• Voltage

• Current

• Real Power in kW

• Reactive Power in kvar

• Apparent Power in kVA

nd date stamps (addr

esses 61

The EPM4500 provides one-second updated inputs, including the following 3-phasetotaled values per 3-phase-meter:

• Energy: kWh and kvarh

EPM 4500 SUB METER – INSTRUCTION MANUAL 4–3

MODBUS COMMUNICATIONS CHAPTER 4: COMMUNICATIONS

• Power: kW, kvar, and kVA

• Power Factor

4.1.7 32-bit Long and Float Data Formats

The EPM4500 supports standard format for 32-bit Long (signed or unsigned). The first of the two 16-bit Modbus register set contains the HIGH order 16 bits of the 32-bit Long data. The second of the two 16-bit Modbus register set contains the LOW order 16 bits of the 32bit Long data.

The EPM4500 supports Intel 32 bit (IEEE) FLOAT format. That means, unlike the standard Long format, the first of the two 16-bit Modbus register set contains the LOW order 16 bits of the 32-bit Float data. The second of the two 16-bit Modbus register set contains the HIGH order 16 bits of the 32-bit Float data.

4–4 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 4: COMMUNICATIONS MODBUS ACTIVATION

4.2 Modbus Activation

4.2.1 Overview

The EPM4500 is shipped with Modbus not activated. To activate the Modbus protocol, it is necessary to use the Hilgraeve HyperTerminal Private Edition software. This software is available from the following website:

http://www.hilgraeve.com/htpe

Once Modbus is activated, the meter will ignore the following ASCII commands unless the login string is sent using the “Key Macros” function within HyperTerminal. Set up “Key Macros” to send the login string (see Logging into the Meter on page 4–6) followed by [ENTER].

Note

IMPORTANT: The log in string must be sent without breaking up packets. A direct connection from a serial port to the EPM4500 RS485 port (via RS232/485 converter) is highly recommended. GE's Ethernet Gateway will break up this login string into packets and prevent login.

The EPM4500 only allows login at 9600, 19200 or 38400 baud when NOT in Modbus mode. This is displayed as HUNT in the meter display under Serial # Registers. Once in Modbus, the EPM4500 only responds at the programmed baud rate.

4.2.2 Configuring a New HyperTerminal Session

Use the following procedure to configure a new HyperTerminal session.

Z Enter the New Connection Name.

Z Select the COM port to connect to the meter.

Z Select the COM port properties. The following window will appear.

Use the setting shown below.

EPM 4500 SUB METER – INSTRUCTION MANUAL 4–5

MODBUS ACTIVATION CHAPTER 4: COMMUNICATIONS

Z Select the File > Properties > Settings > ASCII Setup menu item.

Check the Echo typed characters locally option, as shown below.

4.2.3 Confirming Connection to the EPM4500

To confirm a proper RS485 connection to the EPM4500, enter the following command:

attn -D (followed by the [ENTER] key)

If meter is properly connected, it will respond with a serial number and poll address. Once in Modbus mode, this command will no longer work.

For example, entering the command

attn -D

followed by the [ENTER] key returns:

60005866 256

for a meter with serial number 60005866 and poll address 256.

4.2.4 Logging into the Meter

Use the following procedure to login to the EPM4500.

Z Setup a ‘key macro’ in HyperTerminal by selecting the View > Key

Macros menu item.

Z Click New and select an appropriate macro key sequence (ALT-1 is

used the example below.

Z Enter the following command in the Action area:

attn -S[serialNumber] -5lEvElbAl<ENTER>

Z The password is -s5 followed by the LABLEVEL text spelled

backwards, with the vowels in upper case. This login string must be followed by the ENTER command within the key macro.

For example, for a unit with serial number 60005866, enter the following text:

4–6 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 4: COMMUNICATIONS MODBUS ACTIVATION

4.2.5 Activating Modbus Communications

Use the following procedure to activate Modbus communications.

Z Enter the following command to activate Modbus:

stty -M1 (followed by [ENTER] twice)

Z Select the baud rate by entering the following command.

The baud rate options for Modbus communication are 9600, 19200, and 38400.

stty 19200 (followed by [ENTER] twice)

Z Save Modbus activation by entering:

stty -W1234

Z Display Modbus activation by entering:

stty

Z This command displays meter port setting, baud rate, etc.

If Modbus is active, it returns “Modbus”; if Modbus is not active, it returns “no Modbus”.

For example, consider the following set of commands sets the activates Modbus, sets the baud rate to 19200, and saves the Modbus activation. The text returned by the meter is also indicated.

CIP#stty

hunt 19200 baud 8 bits no parity no echo no modem no modbus

CIP#stty -M1

CIP#stty 19200

CIP#stty -W1234

CIP#stty

hold 19200 baud 8 bits no parity no echo no modem modbus

EPM 4500 SUB METER – INSTRUCTION MANUAL 4–7

MODBUS ACTIVATION CHAPTER 4: COMMUNICATIONS

4.2.6 Changing Modbus Settings

Use the following procedure to change the Modbus address setting:

Z Enter the following command to set the Modbus address:

attn -p#

where

# is replaced by the actual address desired (for example,

attn -p100).

Z Save the Modbus address as follows

attn -W1234

Z Enter the following command to display and verify the Modbus

address:

attn -d

This command displays the meter serial number and the poll/Modbus number.

4.2.7 Logging Out

Z Use one of the following commands to logout of the meter:

attn or exit

Note

Once Modbus is set, it is best to type [HALT] followed by [ENTER] or cycle power to the meter. Otherwise, Modbus will become active one minute after logout.

To log into meter once Modbus is active, use hot keys to program the login sequence. The login sequence must include either the serial number or the Modbus address.

Example hot key sequences are shown below:

attn -S60005866 -3Super3

attn 256 -3Super3

4.2.8 Disabling Modbus Communications

Use the following procedure to disable Modbus communications:

Z Turn off Modbus with the following command:

stty -M0

Z Save Modbus settings:

stty -W1234

4–8 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 4: COMMUNICATIONS MODBUS MEMORY MAP

4.3 Modbus Memory Map

4.3.1 Memory Map

The Modbus memory map is shown below.

Table 4–1: Modbus Memory Map (Sheet 1 of 15)

Hex

Addr

0000

0002

0004

0006

0008 0008 Meter Modbus Address R --- 8-bit Modbus Address in LSB

0009 0009 Baud Rate R

000C 0012 Meter Status R --- Always 1 for Modbus.

000D 0013 Meter Ready R --- Always 1 for Modbus.

000E 0014 Number of Meters Conf igured R --- Always 1 for EPM4500

000F 0015 Number of Real-Time Points Configured R

0010 0016 Number of Interval Points Configured R Returns 0 if intervals are disabled

0011 0017 Number of Max/Min Points Configured R Always returns 0

0012 0018 Maximum Number of Intervals That Can Be Recorded R

0013 0019 Number of slots configured for Scan Transponder R

0014 0020 Current slot being read in Scan Transponder W

Addr Description R/W Units Notes

Fixed Value Registers (Read Only)

0000 Meter Serial Number R hex digits

0002 Meter Serial Number Extension R hex digits Returns same value as address 0000

0004 Meter Version Number R hex digits

0006 Meter Version Number Extension R hex digits Returns same value as address 0000

Setup Information

Dependent upon the number of parameters optioned and the number of meters returned in address 0015

Interval Setup

0031 0049 Store Interval Length R minutes

Read Clock

0032 0050 Internal Time - Hours/Minutes R hours/minutes

0033 0051 Internal Time - Seconds R seconds

0034 0052 Internal Date - Month/Day R month/day

0035 0053 Interval Date - Year R year

0036 0054 Internal Time - Hours/Minutes W hours/minutes

0037 0055 Internal Time - Seconds W month/day

0038 0056 Internal Date - Month/Day W Year 16-bit Unsigned Integer

0039 0057 Interval Date - Year W 16-bit Unsigned Integer

Interval length in minutes must be evenly divisible into 60 (1, 2, 3, 4, 5, 6, 10, 12, 15, 20, 30, 60)

16-bit, Hours: 0-23 (bitmask = FF00) Minutes: 0-59 (bitmask = 00FF

EPM 4500 SUB METER – INSTRUCTION MANUAL 4–9

MODBUS MEMORY MAP CHAPTER 4: COMMUNICATIONS

Table 4–1: Modbus Memory Map (Sheet 2 of 15)

Hex

Addr

003A 0058 Date/Time of Oldest Interval - Hours/Minutes R Hours/Minutes

003B 0059 Date/Time of Oldest Interval - Month/Day R Month/Day

003C 0060 Date/Time of Oldest Interval - Year R Year 16-bit Unsigned Integer

003D 0061 Date/T ime of Newest Interval - Hours/Minutes R Hours/Minutes

003E 0062 Date/Time of Newest Interval - Month/Day R Month/Day

003F 0063 Date/Time of Newest Interval - Year R Year 16 Bit Unsigned Integer

0040 0064

0041 0065 Date/Time of Currently Selected Interval - Month/Day RW Month/Day

0042 0066 Date/T ime of Currently Selected Interval - Year RW Year 16 Bit Unsigned Integer

0043 0067 Data Ready Flag RW

Addr Description R/W Units Notes

16-bit, Hours: 0-23 (bitmask = FF00) Minutes: 0-59 (bitmask = 00FF) DDE Data is COM Compatible, Date/Time Numeric

16-bit Month: 1=Jan., 12=Dec. (bitmask = FF00) Day: 1-31 (bitmask = 00FF) DDE Data is COM Compatible, Date/Time Numeric

16-bit, Hours: 0-23 (bitmask = FF00) Minutes: 0-59 (bitmask = 00FF)

16-bit Month: 1=Jan., 12=Dec. (bitmask = FF00) Day: 1-31 (bitmask = 00FF) DDE Data is COM Compatible, Date/Time Numeric

Date/Time of Currently Selected Interval - Hours/ Minutes

Average Interval Data

RW Hours/Minutes

16-bit, Hours: 0-23 (bitmask = FF00) Minutes: 0-59 (bitmask = 00FF

16-bit Month: 1=Jan., 12=Dec. (bitmask = FF00) Day: 1-31 (bitmask = 00FF) DDE Data is COM Compatible, Date/Time Numeric

16 Bits: Mask out/ignore Bit 15. 0=Data is ready for read 1=Populate registers with timestamp data 2=Invalid Timestamp Requested Stored Dynamic Data Ready for Read

0063 0099 Interval Data Qualifying Register R 16-bit Unsigned Integer, 8 = Invalid Interval

0064

0066* 0102 Meter #1 Three-Phase Total kvar R kvar Stored Interval 2 for Meter #1

0068* 0104 Meter #1 Three-Phase Total kVA R kVA Stored Interval 3 for Meter #1

006A* 0106 Meter #1 Three-Phase Total Power Factor R % Stored Interval 4 for Meter #1

006C* 0108 Meter #2 Three-Phase Total kW R kW Stored Interval 1 for Meter #2

006E* 0110 Meter #2 Three-Phase Total kvar R kvar Stored Interval 2 for Meter #2

0070* 0112 Meter #2 Three-Phase Total kVA R kVA Stored Interval 3 for Meter #2

0072* 0114 Meter #2 Three-Phase Total Power Factor R % Stored Interval 4 for Meter #2

0074* 0116 Meter #3 Three-Phase Total kW R kW Stored Interval 1 for Meter #3

0076* 0118 Meter #3 Three-Phase Total kvar R kvar Stored Interval 2 for Meter #3

0078* 0120 Meter #3 Three-Phase Total kVA R kVA Stored Interval 3 for Meter #3

007A* 0122 Meter #3 Three-Phase Total Power Factor R % Stored Interval 4 for Meter #3

007C* 0124 Meter #4 Three-Phase Total kW R kW Stored Interval 1 for Meter #4

007E* 0126 Meter #4 Three-Phase Total kvar R kvar Stored Interval 2 for Meter #4

0080* 0128 Meter #4 Three-Phase Total kVA R kVA Stored Interval 3 for Meter #4

0100 Meter #1 Three-Phase Total kW R kW Stored Interval 1 for Meter #1

4–10 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 4: COMMUNICATIONS MODBUS MEMORY MAP

Table 4–1: Modbus Memory Map (Sheet 3 of 15)

Hex

Addr

0082* 0130 Meter #4 Three-Phase Total Power Factor R % Stored Interval 4 for Meter #4

0084* 0132 Meter #5 Three-Phase Total kW R kW Stored Interval 1 for Meter #5

0086* 0134 Meter #5 Three-Phase Total kvar R kvar Stored Interval 2 for Meter #5

0088* 0136 Meter #5 Three-Phase Total kVA R kVA Stored Interval 3 for Meter #5

008A* 0138 Meter #5 Three-Phase Total Power Factor R % Stored Interval 4 for Meter #5

008C* 0140 Meter #6 Three-Phase Total kW R kW Stored Interval 1 for Meter #6

008E* 0142 Meter #6 Three-Phase Total kvar R kvar Stored Interval 2 for Meter #6

0090* 0144 Meter #6 Three-Phase Total kVA R kVA Stored Interval 3 for Meter #6

0092* 0146 Meter #6 Three-Phase Total Power Factor R % Stored Interval 4 for Meter #6

0094* 0148 Meter #7 Three-Phase Total kW R kW Stored Interval 1 for Meter #7

0096* 0150 Meter #7 Three-Phase Total kvar R kvar Stored Interval 2 for Meter #7

0098* 0152 Meter #7 Three-Phase Total kVA R kVA Stored Interval 3 for Meter #7

009A* 0154 Meter #7 Three-Phase Total Power Factor R % Stored Interval 4 for Meter #7

009C* 0156 Meter #8 Three-Phase Total kW R kW Stored Interval 1 for Meter #8

009E* 0158 Meter #8 Three-Phase Total kvar R kvar Stored Interval 2 for Meter #8

00A0* 0160 Meter #8 Three-Phase Total kVA R kVA Stored Interval 3 for Meter #8

00A2* 0162 Meter #8 Three-Phase Total Power Factor R % Stored Interval 4 for Meter #8

Addr Description R/W Units Notes

00A4* 0164 Meter #9 Two-Phase Total kW R kW Stored Interval 1 for Meter #9

00A6* 0166 Meter #9 Two-Phase Total kvar R kvar Stored Interval 2 for Meter #9

00A8* 0168 Meter #9 Two-Phase Total kVA R kVA Stored Interval 3 for Meter #9

00AA* 0170 Meter #9 Two-Phase Total Power Factor R % Stored Interval 4 for Meter #9

00AC* 0172 Meter #10 Two-Phase Total kW R kW Stored Interval 1 for Meter #10

00AE* 0174 Meter #10 Two-Phase Total kvar R kvar Stored Interval 2 for Meter #10

00B0* 0176 Meter #10 Two-Phase Total kVA R kVA Stored Interval 3 for Meter #10

00B2* 0178 Meter #10 Two-Phase Total Power Factor R % Stored Interval 4 for Meter #10

00B4* 0180 Meter #11 Two-Phase Total kW R kW Stored Interval 1 for Meter #11

00B6* 0182 Meter #11 Two-Phase Total kvar R kvar Stored Interval 2 for Meter #11

00B8* 0184 Meter #11 Two-Phase Total kVA R kVA Stored Interval 3 for Meter #11

00BA* 0186 Meter #11 Two-Phase Total Power Factor R % Stored Interval 4 for Meter #11

00BC* 0188 Meter #12 Two-Phase Total kW R kW Stored Interval 1 for Meter #12

00BE* 0190 Meter #12 Two-Phase Total kvar R kvar Stored Interval 2 for Meter #12

00C0* 0192 Meter #12 Two-Phase Total kVA R kVA Stored Interval 3 for Meter #12

00C2* 0194 Meter #12 Two-Phase Total Power Factor R % Stored Interval 4 for Meter #12

00C4* 0196 Meter #13 Single-Phase Total kW R kW Stored Interval 1 for Meter #13

00C6* 0198 Meter #13 Single-Phase Total kvar R kvar Stored Interval 2 for Meter #13

EPM 4500 SUB METER – INSTRUCTION MANUAL 4–11

MODBUS MEMORY MAP CHAPTER 4: COMMUNICATIONS

Table 4–1: Modbus Memory Map (Sheet 4 of 15)

Hex

Addr

00C8* 0200 Meter #13 Single-Phase Total kVA R kVA Stored Interval 3 for Meter #13

00CA* 0202 Meter #13 Single-Phase Total Power Factor R % Stored Interval 4 for Meter #13

00CC* 0204 Meter #14 Single-Phase Total kW R kW Stored Interval 1 for Meter #14

00CE* 0206 Meter #14 Single-Phase Total kvar R kvar Stored Interval 2 for Meter #14

00D0* 0208 Meter #14 Single-Phase Total kVA R kVA Stored Interval 3 for Meter #14

00D2* 0210 Meter #14 Single-Phase Total Power Factor R % Stored Interval 4 for Meter #14

00D4* 0212 Meter #15 Single-Phase Total kW R kW Stored Interval 1 for Meter #15

00D6* 0214 Meter #15 Single-Phase Total kvar R kvar Stored Interval 2 for Meter #15

00D8* 0216 Meter #15 Single-Phase Total kVA R kVA Stored Interval 3 for Meter #15

00DA* 0218 Meter #15 Single-Phase Total Power Factor R % Stored Interval 4 for Meter #15

00DC* 0220 Meter #16 Single-Phase Total kW R kW Stored Interval 1 for Meter #16

00DE* 0222 Meter #16 Single-Phase Total kvar R kvar Stored Interval 2 for Meter #16

00E0* 0224 Meter #16 Single-Phase Total kVA R kVA Stored Interval 3 for Meter #16

00E2* 0226 Meter #16 Single-Phase Total Power Factor R % Stored Interval 4 for Meter #16

00E4* 0228 Meter #17 Single-Phase Total kW R kW Stored Interval 1 for Meter #17

00E6* 0230 Meter #17 Single-Phase Total kvar R kvar Stored Interval 2 for Meter #17

00E8* 0232 Meter #17 Single-Phase Total kVA R kVA Stored Interval 3 for Meter #17

Addr Description R/W Units Notes

00EA* 0234 Meter #17 Single-Phase Total Power Factor R % Stored Interval 4 for Meter #17

00EC* 0236 Meter #18 Single-Phase Total kW R kW Stored Interval 1 for Meter #18

00EE* 0238 Meter #18 Single-Phase Total kvar R kvar Stored Interval 2 for Meter #18

00F0* 0240 Meter #18 Single-Phase Total kVA R kVA Stored Interval 3 for Meter #18

00F2* 0242 Meter #18 Single-Phase Total Power Factor R % Stored Interval 4 for Meter #18

00F4* 0244 Meter #19 Single-Phase Total kW R kW Stored Interval 1 for Meter #19

00F6* 0246 Meter #19 Single-Phase Total kvar R kvar Stored Interval 2 for Meter #19

00F8* 0248 Meter #19 Single-Phase Total kVA R kVA Stored Interval 3 for Meter #19

00FA* 0250 Meter #19 Single-Phase Total Power Factor R % Stored Interval 4 for Meter #19

00FC* 0252 Meter #20 Single-Phase Total kW R kW Stored Interval 1 for Meter #20

00FE* 0254 Meter #20 Single-Phase Total kvar R kvar Stored Interval 2 for Meter #20

0100* 0256 Meter #20 Single-Phase Total kVA R kVA Stored Interval 3 for Meter #20

0102* 0258 Meter #20 Single-Phase Total Power Factor R % Stored Interval 4 for Meter #20

0104* 0260 Meter #21 Single-Phase Total kW R kW Stored Interval 1 for Meter #21

0106* 0262 Meter #21 Single-Phase Total kvar R kvar Stored Interval 2 for Meter #21

0108* 0264 Meter #21 Single-Phase Total kVA R kVA Stored Interval 3 for Meter #21

010A* 0266 Meter #21 Single-Phase Total Power Factor R % Stored Interval 4 for Meter #21

010C* 0268 Meter #22 Single-Phase Total kW R kW Stored Interval 1 for Meter #22

4–12 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 4: COMMUNICATIONS MODBUS MEMORY MAP

Table 4–1: Modbus Memory Map (Sheet 5 of 15)

Hex

Addr

010E* 0270 Meter #22 Single-Phase Total kvar R kvar Stored Interval 2 for Meter #22

0110* 0272 Meter #22 Single-Phase Total kVA R kVA Stored Interval 3 for Meter #22

0112* 0274 Meter #22 Single-Phase Total Power Factor R % Stored Interval 4 for Meter #22

0114* 0276 Meter #23 Single-Phase Total kW R kW Stored Interval 1 for Meter #23

0116* 0278 Meter #23 Single-Phase Total kvar R kvar Stored Interval 2 for Meter #23

0118* 0280 Meter #23 Single-Phase Total kVA R kVA Stored Interval 3 for Meter #23

011A* 0282 Meter #23 Single-Phase Total Power Factor R % Stored Interval 4 for Meter #23

011C* 0284 Meter #24 Single-Phase Total kW R kW Stored Interval 1 for Meter #24

011E* 0286 Meter #24 Single-Phase Total kvar R kvar Stored Interval 2 for Meter #24

0120* 0288 Meter #24 Single-Phase Total kVA R kVA Stored Interval 3 for Meter #24

0122* 0290 Meter #24 Single-Phase Total Power Factor R % Stored Interval 4 for Meter #24

0162* 0354 Frequency (Phase A) R Hz Phase-to-Ground Instantaneous Frequency

016A* 0362 Voltage (A-N) R V Phase-to-Ground Instantaneous Voltage

016C* 0364 Voltage (B-N) R V Phase-to-Ground Instantaneous Voltage

016E* 0366 Voltage (C-N) R V Phase-to-Ground Instantaneous Voltage

0170* 0368 Voltage (CT01) R V CT #1 Instantaneous Voltage

Addr Description R/W Units Notes

Metered Values (Instantaneous Data)

0172* 0370 Amps (CT01) R A CT #1 Instantaneous Current

0174* 0372 kW (CT01) R kW CT #1 Instantaneous Power

0176* 0374 kvar (CT01) R kvar CT #1 Instantaneous Reactive Power

0178* 0376 kVA (CT01) R kVA CT #1 Instantaneous Apparent Power

017A* 0378 Voltage (CT02) R V CT #2 Instantaneous Voltage

017C* 0380 Amps (CT02) R A CT #2 Instantaneous Current

017E* 0382 kW (CT02) R kW CT #2 Instantaneous Power

0180* 0384 kvar (CT02) R kvar CT #2 Instantaneous Reactive Power

0182* 0386 kVA (CT02) R kVA CT #2 Instantaneous Apparent Power

0184* 0388 Voltage (CT03) R V CT #3 Instantaneous Voltage

0186* 0390 Amps (CT03) R A CT #3 Instantaneous Current

0188* 0392 kW (CT03) R kW CT #3 Instantaneous Power

018A* 0394 kvar (CT03) R kvar CT #3 Instantaneous Reactive Power

018C* 0396 kVA (CT03) R kVA CT #3 Instantaneous Apparent Power

018E* 0398 Voltage (CT04) R V CT #4 Instantaneous Voltage

0190* 0400 Amps (CT04) R A CT #4 Instantaneous Current

0192* 0402 kW (CT04) R kW CT #4 Instantaneous Power

0194* 0404 kvar (CT04) R kvar CT #4 Instantaneous Reactive Power

EPM 4500 SUB METER – INSTRUCTION MANUAL 4–13

MODBUS MEMORY MAP CHAPTER 4: COMMUNICATIONS

Table 4–1: Modbus Memory Map (Sheet 6 of 15)

Hex

Addr

0196* 0406 kVA (CT04) R kVA CT #4 Instantaneous Apparent Power

0198* 0408 Voltage (CT05) R V CT #5 Instantaneous Voltage

019A* 0410 Amps (CT05) R A CT #5 Instantaneous Current

019C* 0412 kW (CT05) R kW CT #5 Instantaneous Power

019E* 0414 kvar (CT05) R kvar CT #5 Instantaneous Reactive Power

01A0* 0416 kVA (CT05) R kVA CT #5 Instantaneous Apparent Power

01A2* 0418 Voltage (CT06) R V CT #6 Instantaneous Voltage

01A4* 0420 Amps (CT06) R A CT #6 Instantaneous Current

01A6* 0422 kW (CT06) R kW CT #6 Instantaneous Power

01A8* 0424 kvar (CT06) R kvar CT #6 Instantaneous Reactive Power

01AA* 0426 kVA (CT06) R kVA CT #6 Instantaneous Apparent Power

01AC* 0428 Voltage (CT07) R V CT #7 Instantaneous Voltage

01AE* 0430 Amps (CT07) R A CT #7 Instantaneous Current

01B0* 0432 kW (CT07) R kW CT #7 Instantaneous Power

01B2* 0434 kvar (CT07) R kvar CT #7 Instantaneous Reactive Power

01B4* 0436 kVA (CT07) R kVA CT #7 Instantaneous Apparent Power

01B6* 0438 Voltage (CT08) R V CT #8 Instantaneous Voltage

Addr Description R/W Units Notes

01B8* 0440 Amps (CT08) R A CT #8 Instantaneous Current

01BA* 0442 kW (CT08) R kW CT #8 Instantaneous Power

01BC* 0444 kvar (CT08) R kvar CT #8 Instantaneous Reactive Power

01BE* 0446 kVA (CT08) R kVA CT #8 Instantaneous Apparent Power

01C0* 0448 Voltage (CT09) R V CT #9 Instantaneous Voltage

01C2* 0450 Amps (CT09) R A CT #9 Instantaneous Current

01C4* 0452 kW (CT09) R kW CT #9 Instantaneous Power

01C6* 0454 kvar (CT09) R kvar CT #9 Instantaneous Reactive Power

01C8* 0456 kVA (CT09) R kVA CT #9 Instantaneous Apparent Power

01CA* 0458 Voltage (CT10) R V CT #10 Instantaneous Voltage

01CC* 0460 Amps (CT10) R A CT #10 Instantaneous Current

01CE* 0462 kW (CT10) R kW CT #10 Instantaneous Power

01D0* 0464 kvar (CT10) R kvar CT #10 Instantaneous Reactive Power

01D2* 0466 kVA (CT10) R kVA CT #10 Instantaneous Apparent Power

01D4* 0468 Voltage (CT11) R V CT #11 Instantaneous Voltage

01D6* 0470 Amps (CT11) R A CT #11 Instantaneous Current

01D8* 0472 kW (CT11) R kW CT #11 Instantaneous Power

01DA* 0474 kvar (CT11) R kvar CT #11 Instantaneous Reactive Power

4–14 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 4: COMMUNICATIONS MODBUS MEMORY MAP

Table 4–1: Modbus Memory Map (Sheet 7 of 15)

Hex

Addr

01DC* 0476 kVA (CT11) R kVA CT #11 Instantaneous Apparent Power

01DE* 0478 Voltage (CT12) R V CT #12 Instantaneous Voltage

01E0* 0480 Amps (CT12) R A CT #12 Instantaneous Current

01E2* 0482 kW (CT12) R kW CT #12 Instantaneous Power

01E4* 0484 kvar (CT12) R kvar CT #12 Instantaneous Reactive Power

01E6* 0486 kVA (CT12) R kVA CT #12 Instantaneous Apparent Power

01E8* 0488 Voltage (CT13) R V CT #13 Instantaneous Voltage

01EA* 0490 Amps (CT13) R A CT #13 Instantaneous Current

01EC* 0492 kW (CT13) R kW CT #13 Instantaneous Power

01EE* 0494 kvar (CT13) R kvar CT #13 Instantaneous Reactive Power

01F0* 0496 kVA (CT13) R kVA CT #13 Instantaneous Apparent Power

01F2* 0498 Voltage (CT14) R V CT #14 Instantaneous Voltage

01F4* 0500 Amps (CT14) R A CT #14 Instantaneous Current

01F6* 0502 kW (CT14) R kW CT #14 Instantaneous Power

01F8* 0504 kvar (CT14) R kvar CT #14 Instantaneous Reactive Power

01FA* 0506 kVA (CT14) R kVA CT #14 Instantaneous Apparent Power

01FC* 0508 Voltage (CT15) R V CT #15 Instantaneous Voltage

Addr Description R/W Units Notes

01FE* 0510 Amps (CT15) R A CT #15 Instantaneous Current

200* 0512 kW (CT15) R kW CT #15 Instantaneous Power

0202* 0514 kvar (CT15) R kvar CT #15 Instantaneous Reactive Power

0204* 0516 kVA (CT15) R kVA CT #15 Instantaneous Apparent Power

0206* 0518 Voltage (CT16) R V CT #16 Instantaneous Voltage

0208* 0520 Amps (CT16) R A CT #16 Instantaneous Current

020A* 0522 kW (CT16) R kW CT #16 Instantaneous Power

020C* 0524 kvar (CT16) R kvar CT #16 Instantaneous Reactive Power

020E* 0526 kVA (CT16) R kVA CT #16 Instantaneous Apparent Power

0210* 0528 Voltage (CT17) R V CT #17 Instantaneous Voltage

0212* 0530 Amps (CT17) R A CT #17 Instantaneous Current

0214* 0532 kW (CT17) R kW CT #17 Instantaneous Power

0216* 0534 kvar (CT17) R kvar CT #17 Instantaneous Reactive Power

0218* 0536 kVA (CT17) R kVA CT #17 Instantaneous Apparent Power

021A* 0538 Voltage (CT18) R V CT #18 Instantaneous Voltage

021C* 0540 Amps (CT18) R A CT #18 Instantaneous Current

021E* 0542 kW (CT18) R kW CT #18 Instantaneous Power

0220* 0544 kvar (CT18) R kvar CT #18 Instantaneous Reactive Power

EPM 4500 SUB METER – INSTRUCTION MANUAL 4–15

MODBUS MEMORY MAP CHAPTER 4: COMMUNICATIONS

Table 4–1: Modbus Memory Map (Sheet 8 of 15)

Hex

Addr

0222* 0546 kVA (CT18) R kVA CT #18 Instantaneous Apparent Power

0224* 0548 Voltage (CT19) R V CT #19 Instantaneous Voltage

0226* 0550 Amps (CT19) R A CT #19 Instantaneous Current

0228* 0552 kW (CT19) R kW CT #19 Instantaneous Power

022A* 0554 kvar (CT19) R kvar CT #19 Instantaneous Reactive Power

022C* 0556 kVA (CT19) R kVA CT #19 Instantaneous Apparent Power

022E* 0558 Voltage (CT20) R V CT #20 Instantaneous Voltage

0230* 0560 Amps (CT20) R A CT #20 Instantaneous Current

0232* 0562 kW (CT20) R kW CT #20 Instantaneous Power

0234* 0564 kvar (CT20) R kvar CT #20 Instantaneous Reactive Power

0236* 0566 kVA (CT20) R kVA CT #20 Instantaneous Apparent Power

0238* 0568 Voltage (CT21) R V CT #21 Instantaneous Voltage

023A* 0570 Amps (CT21) R A CT #21 Instantaneous Current

023C* 0572 kW (CT21) R kW CT #21 Instantaneous Power

023E* 0574 kvar (CT21) R kvar CT #21 Instantaneous Reactive Power

0240* 0576 kVA (CT21) R kVA CT #21 Instantaneous Apparent Power

0242* 0578 Voltage (CT22) R V CT #22 Instantaneous Voltage

Addr Description R/W Units Notes

0244* 0580 Amps (CT22) R A CT #22 Instantaneous Current

0246* 0582 kW (CT22) R kW CT #22 Instantaneous Power

0248* 0584 kvar (CT22) R kvar CT #22 Instantaneous Reactive Power

024A* 0586 kVA (CT22) R kVA CT #22 Instantaneous Apparent Power

024C* 0588 Voltage (CT23) R V CT #23 Instantaneous Voltage

024E* 0590 Amps (CT23) R A CT #23 Instantaneous Current

0250* 0592 kW (CT23) R kW CT #23 Instantaneous Power

0252* 0594 kvar (CT23) R kvar CT #23 Instantaneous Reactive Power

0254* 0596 kVA (CT23) R kVA CT #23 Instantaneous Apparent Power

0256* 0598 Voltage (CT24) R V CT #24 Instantaneous Voltage

0258* 0600 Amps (CT24) R A CT #24 Instantaneous Current

025A* 0602 kW (CT24) R kW CT #24 Instantaneous Power

025C* 0604 kvar (CT24) R kvar CT #24 Instantaneous Reactive Power

025E* 0606 kVA (CT24) R kVA CT #24 Instantaneous Apparent Power

4–16 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 4: COMMUNICATIONS MODBUS MEMORY MAP

Table 4–1: Modbus Memory Map (Sheet 9 of 15)

Hex

Addr

0288* 0648 Meter #1 Three-Phase kWh R kWh Meter #1 Real Time Input 1

028A* 0650 Meter #1 Three-Phase kvarh R kvarh Meter #1 Real Time Input 2

028C* 0652 Meter #1 Three-Phase kW R kW Meter #1 Real Time Input 3

028E* 0654 Meter #1 Three-Phase kvar R kvar Meter #1 Real Time Input 4

0290* 0656 Meter #1 Three-Phase kVA R kVA Meter #1 Real T ime Input 5

0292* 0658 Meter #1 Three-Phase Power Factor R % Meter #1 Real T ime Input 6

0294* 0660 Meter #2 Three-Phase kWh R kWh Meter #2 Real Time Input 1

0296* 0662 Meter #2 Three-Phase kvarh R kvarh Meter #2 Real Time Input 2

0298* 0664 Meter #2 Three-Phase kW R kW Meter #2 Real Time Input 3

029A* 0666 Meter #2 Three-Phase kvar R kvar Meter #2 Real Time Input 4

029C* 0668 Meter #2 Three-Phase kVA R kVA Meter #2 Real Time Input 5

029E* 0670 Meter #2 Three-Phase Power Factor R % Meter #2 Real T ime Input 6

02A0* 0672 Meter #3 Three-Phase kWh R kWh Meter #3 Real T ime Input 1

02A2* 0674 Meter #3 Three-Phase kvarh R kvarh Meter #3 Real Time Input 2

02A4 0676 Meter #3 Three-Phase kW R kW Meter #3 Real T ime Input 3

02A6* 0678 Meter #3 Three-Phase kvar R kvar Meter #3 Real Time Input 4

Addr Description R/W Units Notes

Three-Phase Metered Values (Fast Poll)

02A8* 0680 Meter #3 Three-Phase kVA R kVA Meter #3 Real Time Input 5

02AA* 0682 Meter #3 Three-Phase Power Factor R % Meter #3 Real Time Input 6

02AC* 0684 Meter #4 Three-Phase kWh R kWh Meter #4 Real T ime Input 1

02AE* 0686 Meter #4 Three-Phase kvarh R kvarh Meter #4 Real T ime Input 2

02B0* 0688 Meter #4 Three-Phase kW R kW Meter #4 Real Time Input 3

02B2* 0690 Meter #4 Three-Phase kvar R kvar Meter #4 Real Time Input 4

02B4* 0692 Meter #4 Three-Phase kVA R kVA Meter #4 Real Time Input 5

02B6* 0694 Meter #4 Three-Phase Power Factor R % Meter #4 Real Time Input 6

02B8* 0696 Meter #5 Three-Phase kWh R kWh Meter #5 Real T ime Input 1

02BA* 0698 Meter #5 Three-Phase kvarh R kvarh Meter #5 Real Time Input 2

02BC* 0700 Meter #5 Three-Phase kW R kW Meter #5 Real Time Input 3

02BE* 0702 Meter #5 Three-Phase kvar R kvar Meter #5 Real T ime Input 4

02C0* 0704 Meter #5 Three-Phase kVA R kVA Meter #5 Real Time Input 5

02C2* 0706 Meter #5 Three-Phase Power Factor R % Meter #5 Real Time Input 6

02C4 0708 Meter #6 Three-Phase kWh R kWh Meter #6 Real Time Input 1

02C6* 0710 Meter #6 Three-Phase kvarh R kvarh Meter #6 Real Time Input 2

02C8* 0712 Meter #6 Three-Phase kW R kW Meter #6 Real Time Input 3

02CA* 0714 Meter #6 Three-Phase kvar R kvar Meter #6 Real T ime Input 4

EPM 4500 SUB METER – INSTRUCTION MANUAL 4–17

MODBUS MEMORY MAP CHAPTER 4: COMMUNICATIONS

Table 4–1: Modbus Memory Map (Sheet 10 of 15)

Hex

Addr

02CC* 0716 Meter #6 Three-Phase kVA R kVA Meter #6 Real Time Input 5

02CE* 0718 Meter #6 Three-Phase Power Factor R % Meter #6 Real Time Input 6

02D0* 0720 Meter #7 Three-Phase kWh R kWh Meter #7 Real Time Input 1

02D2* 0722 Meter #7 Three-Phase kvarh R kvarh Meter #7 Real Time Input 2

02D4* 0724 Meter #7 Three-Phase kW R kW Meter #7 Real T ime Input 3

02D6* 0726 Meter #7 Three-Phase kvar R kvar Meter #7 Real Time Input 4

02D8 0728 Meter #7 Three-Phase kVA R kVA Meter #7 Real Time Input 5

02DA* 0730 Meter #7 Three-Phase Power Factor R % Meter #7 Real Time Input 6

02DC* 0732 Meter #8 Three-Phase kWh R kWh Meter #8 Real Time Input 1

02DE* 0734 Meter #8 Three-Phase kvarh R kvarh Meter #8 Real Time Input 2

02E0* 0736 Meter #8 Three-Phase kW R kW Meter #8 Real Time Input 3

02E2* 0738 Meter #8 Three-Phase kvar R kvar Meter #8 Real Time Input 4

02E4* 0740 Meter #8 Three-Phase kVA R kVA Meter #8 Real Time Input 5

02E6* 0742 Meter #8 Three-Phase Power Factor R % Meter #8 Real T ime Input 6

02E8* 0744 Meter #9 Phase kWh R kWh Meter #9 Real Time Input 1

02EA* 0746 Meter #9 Phase kvarh R kvarh Meter #9 Real Time Input 2

02EC* 0748 Meter #9 Phase kW R kW Meter #9 Real T ime Input 3

Addr Description R/W Units Notes

02EE* 0750 Meter #9 Phase kvar R kvar Meter #9 Real T ime Input 4

02F0* 0752 Meter #9 Phase kVA R kVA Meter #9 Real Time Input 5

02F2* 0754 Meter #9 Phase Power Factor R % Meter #9 Real Time Input 6

02F4* 0756 Meter #10 Phase kWh R kWh Meter #10 Real Time Input 1

02F6* 0758 Meter #10 Phase kvarh R kvarh Meter #10 Real Time Input 2

02F8* 0760 Meter #10 Phase kW R kW Meter #10 Real Time Input 3

02FA* 0762 Meter #10 Phase kvar R kvar Meter #10 Real T ime Input 4

02FC* 0764 Meter #10 Phase kVA R kVA Meter #10 Real Time Input 5

02FE* 0766 Meter #10 Phase Power Factor R % Meter #10 Real Time Input 6

0300* 0768 Meter #11 Phase kWh R kWh Meter #11 Real Time Input 1

0302* 0770 Meter #11 Phase kvarh R kvarh Meter #11 Real Time Input 2

0304* 0772 Meter #11 Phase kW R kW Meter #11 Real Time Input 3

0306* 0774 Meter #11 Phase kvar R kvar Meter #11 Real Time Input 4

0308* 0776 Meter #11 Phase kVA R kVA Meter #11 Real Time Input 5

030A* 0778 Meter #11 Phase Power Factor R % Meter #11 Real T ime Input 6

030C* 0780 Meter #12 Phase kWh R kWh Meter #12 Real T ime Input 1

030E* 0782 Meter #12 Phase kvarh R kvarh Meter #12 Real Time Input 2

0310* 0784 Meter #12 Phase kW R kW Meter #12 Real Time Input 3

4–18 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 4: COMMUNICATIONS MODBUS MEMORY MAP

Table 4–1: Modbus Memory Map (Sheet 11 of 15)

Hex

Addr

0312* 0786 Meter #12 Phase kvar R kvar Meter #12 Real Time Input 4

0314* 0788 Meter #12 Phase kVA R kVA Meter #12 Real Time Input 5

0316* 0790 Meter #12 Phase Power Factor R % Meter #12 Real Time Input 6

0318* 0792 Meter #13 Phase kWh R kWh Meter #13 Real Time Input 1

031A* 0794 Meter #13 Phase kvarh R kvarh Meter #13 Real Time Input 2

031C* 0796 Meter #13 Phase kW R kW Meter #13 Real T ime Input 3

031E* 0798 Meter #13 Phase kvar R kvar Meter #13 Real T ime Input 4

0320* 0800 Meter #13 Phase kVA R kVA Meter #13 Real Time Input 5

0322* 0802 Meter #13 Phase Power Factor R % Meter #13 Real Time Input 6

0324* 0804 Meter #14 Phase kWh R kWh Meter #14 Real Time Input 1

0326* 0806 Meter #14 Phase kvarh R kvarh Meter #14 Real Time Input 2

0328* 0808 Meter #14 Phase kW R kW Meter #14 Real Time Input 3

032A* 0810 Meter #14 Phase kvar R kvar Meter #14 Real Time Input 4

032C* 0812 Meter #14 Phase kVA R kVA Meter #14 Real T ime Input 5

032E* 0814 Meter #14 Phase Power Factor R % Meter #14 Real Time Input 6

0330* 0816 Meter #15 Phase kWh R kWh Meter #15 Real Time Input 1

0332* 0818 Meter #15 Phase kvarh R kvarh Meter #15 Real Time Input 2

Addr Description R/W Units Notes

0334* 0820 Meter #15 Phase kW R kW Meter #15 Real Time Input 3

0336* 0822 Meter #15 Phase kvar R kvar Meter #15 Real Time Input 4

0338* 0824 Meter #15 Phase kVA R kVA Meter #15 Real Time Input 5

033A* 0826 Meter #15 Phase Power Factor R % Meter #15 Real T ime Input 6

033C* 0828 Meter #16 Phase kWh R kWh Meter #16 Real Time Input 1

033E* 0830 Meter #16 Phase kvarh R kvarh Meter #16 Real Time Input 2

0340* 0832 Meter #16 Phase kW R kW Meter #16 Real Time Input 3

0342* 0834 Meter #16 Phase kvar R kvar Meter #16 Real Time Input 4

0344* 0836 Meter #16 Phase kVA R kVA Meter #16 Real Time Input 5

0346* 0838 Meter #16 Phase Power Factor R % Meter #16 Real Time Input 6

0348* 0840 Meter #17 Phase kWh R kWh Meter #17 Real Time Input 1

034A* 0842 Meter #17 Phase kvarh R kvarh Meter #17 Real Time Input 2

034C* 0844 Meter #17 Phase kW R kW Meter #17 Real T ime Input 3

034E* 0846 Meter #17 Phase kvar R kvar Meter #17 Real T ime Input 4

0350* 0848 Meter #17 Phase kVA R kVA Meter #17 Real Time Input 5

0352* 0850 Meter #17 Phase Power Factor R % Meter #17 Real Time Input 6

0354* 0852 Meter #18 Phase kWh R kWh Meter #18 Real Time Input 1

0356* 0854 Meter #18 Phase kvarh R kvarh Meter #18 Real Time Input 2

EPM 4500 SUB METER – INSTRUCTION MANUAL 4–19

MODBUS MEMORY MAP CHAPTER 4: COMMUNICATIONS

Table 4–1: Modbus Memory Map (Sheet 12 of 15)

Hex

Addr

0358* 0856 Meter #18 Phase kW R kW Meter #18 Real Time Input 3

035A* 0858 Meter #18 Phase kvar R kvar Meter #18 Real Time Input 4

035C* 0860 Meter #18 Phase kVA R kVA Meter #18 Real T ime Input 5

035E* 0862 Meter #18 Phase Power Factor R % Meter #18 Real Time Input 6

0360* 0864 Meter #19 Phase kWh R kWh Meter #19 Real Time Input 1

0362* 0866 Meter #19 Phase kvarh R kvarh Meter #19 Real Time Input 2

0364* 0868 Meter #19 Phase kW R kW Meter #19 Real Time Input 3

0366* 0870 Meter #19 Phase kvar R kvar Meter #19 Real Time Input 4

0368* 0872 Meter #19 Phase kVA R kVA Meter #19 Real Time Input 5

036A* 0874 Meter #19 Phase Power Factor R % Meter #19 Real T ime Input 6

036C* 0876 Meter #20 Phase kWh R kWh Meter #20 Real T ime Input 1

036E* 0878 Meter #20 Phase kvarh R kvarh Meter #20 Real Time Input 2

0370* 0880 Meter #20 Phase kW R kW Meter #20 Real Time Input 3

0372* 0882 Meter #20 Phase kvar R kvar Meter #20 Real Time Input 4

0374* 0884 Meter #20 Phase kVA R kVA Meter #20 Real Time Input 5

0376* 0886 Meter #20 Phase Power Factor R % Meter #20 Real Time Input 6

0378* 0888 Meter #21 Phase kWh R kWh Meter #21 Real Time Input 1

Addr Description R/W Units Notes

037A* 0890 Meter #21 Phase kvarh R kvarh Meter #21 Real Time Input 2

037C* 0892 Meter #21 Phase kW R kW Meter #21 Real T ime Input 3

037E* 0894 Meter #21 Phase kvar R kvar Meter #21 Real T ime Input 4

0380* 0896 Meter #21 Phase kVA R kVA Meter #21 Real Time Input 5

0382* 0898 Meter #21 Phase Power Factor R % Meter #21 Real Time Input 6

0384* 0900 Meter #22 Phase kWh R kWh Meter #22 Real Time Input 1

0386* 0902 Meter #22 Phase kvarh R kvarh Meter #22 Real Time Input 2

0388* 0904 Meter #22 Phase kW R kW Meter #22 Real Time Input 3

038A* 0906 Meter #22 Phase kvar R kvar Meter #22 Real Time Input 4

038C* 0908 Meter #22 Phase kVA R kVA Meter #22 Real T ime Input 5

038E* 0910 Meter #22 Phase Power Factor R % Meter #22 Real Time Input 6

0390* 0912 Meter #23 Phase kWh R kWh Meter #23 Real Time Input 1

0392* 0914 Meter #23 Phase kvarh R kvarh Meter #23 Real Time Input 2

0394* 0916 Meter #23 Phase kW R kW Meter #23 Real Time Input 3

0396* 0918 Meter #23 Phase kvar R kvar Meter #23 Real Time Input 4

0398* 0920 Meter #23 Phase kVA R kVA Meter #23 Real Time Input 5

039A* 0922 Meter #23 Phase Power Factor R % Meter #23 Real T ime Input 6

039C* 0924 Meter #24 Phase kWh R kWh Meter #24 Real T ime Input 1

4–20 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 4: COMMUNICATIONS MODBUS MEMORY MAP

Table 4–1: Modbus Memory Map (Sheet 13 of 15)

Hex

Addr

039E* 0926 Meter #24 Phase kvarh R kvarh Meter #24 Real Time Input 2

03A0* 0928 Meter #24 Phase kW R kW Meter #24 Real Time Input 3

03A2* 0930 Meter #24 Phase kvar R kvar Meter #24 Real Time Input 4

03A4* 0932 Meter #24 Phase kVA R kVA Meter #24 Real Time Input 5

03A6* 0934 Meter #24 Phase Power Factor R % Meter #24 Real Time Input 6

03E8* 1000 Meter #1 THD Phase A R % Meter #1 Total Harmonic Distortion

03EA* 1002 Meter #1 Phase Angle A R degrees Meter #1 Phase Angle

03EC* 1004 Meter #1 Phase-to-Phase Voltage A R V Meter #1 Instantaneous Voltage

03EE* 1006 Meter #1 THD Phase B R % Meter #1 Total Harmonic Distortion

03F0* 1008 Meter #1 Phase Angle B R degrees Meter #1 Phase Angle

03F2* 1010 Meter #1 Phase-to-Phase Voltage B R V Meter #1 Instantaneous Voltage

03F4* 1012 Meter #1 THD Phase C R % Meter #1 Total Harmonic Distortion

03F6* 1014 Meter #1 Phase Angle C R degrees Meter #1 Phase Angle

03F8* 1016 Meter #1 Phase-to-Phase Voltage C R V Meter #1 Instantaneous Voltage

03FA* 1018 Meter #2 THD Phase A R % Meter #2 Total Harmonic Distortion

03FC* 1020 Meter #2 Phase Angle A R degrees Meter #2 Phase Angle

Addr Description R/W Units Notes

Real Time Data

03FE* 1022 Meter #2 Phase-to-Phase Voltage A R V Meter #2 Instantaneous Voltage

0400* 1024 Meter #2 THD Phase B R % Meter #2 Total Harmonic Distortion

0402* 1026 Meter #2 Phase Angle B R degrees Meter #2 Phase Angle

0404* 1028 Meter #2 Phase-to-Phase Voltage B R V Meter #2 Instantaneous Voltage

0406* 1030 Meter #2 THD Phase C R % Meter #2 Total Harmonic Distortion

0408* 1032 Meter #2 Phase Angle C R degrees Meter #2 Phase Angle

040A* 1034 Meter #2 Phase-to-Phase Voltage C R V Meter #2 Instantaneous Voltage

040C* 1036 Meter #3 THD Phase A R % Meter #3 Total Harmonic Distortion

040E* 1038 Meter #3 Phase Angle A R degrees Meter #3 Phase Angle

0410* 1040 Meter #3 Phase-to-Phase Voltage A R V Meter #3 Instantaneous Voltage

0412* 1042 Meter #3 THD Phase B R % Meter #3 Total Harmonic Distortion

0414* 1044 Meter #3 Phase Angle B R degrees Meter #3 Phase Angle

0416* 1046 Meter #3 Phase-to-Phase Voltage B R V Meter #3 Instantaneous Voltage

0418* 1048 Meter #3 THD Phase C R % Meter #3 Total Harmonic Distortion

041A* 1050 Meter #3 Phase Angle C R degrees Meter #3 Phase Angle

041C* 1052 Meter #3 Phase-to-Phase Voltage C R V Meter #3 Instantaneous Voltage

041E* 1054 Meter #4 THD Phase A R % Meter #4 Total Harmonic Distortion

0420* 1056 Meter #4 Phase Angle A R degrees Meter #4 Phase Angle

EPM 4500 SUB METER – INSTRUCTION MANUAL 4–21

MODBUS MEMORY MAP CHAPTER 4: COMMUNICATIONS

Table 4–1: Modbus Memory Map (Sheet 14 of 15)

Hex

Addr

0422* 1058 Meter #4 Phase-to-Phase Voltage A R V Meter #4 Instantaneous Voltage

0424* 1060 Meter #4 THD Phase B R % Meter #4 Total Harmonic Distortion

0426* 1062 Meter #4 Phase Angle B R degrees Meter #4 Phase Angle

0428* 1064 Meter #4 Phase-to-Phase Voltage B R V Meter #4 Instantaneous Voltage

042A* 1066 Meter #4 THD Phase C R % Meter #4 Total Harmonic Distortion

042C* 1068 Meter #4 Phase Angle C R degrees Meter #4 Phase Angle

042E* 1070 Meter #4 Phase-to-Phase Voltage C R V Meter #4 Instantaneous Voltage

0430* 1072 Meter #5 THD Phase A R % Meter #5 Total Harmonic Distortion

0432* 1074 Meter #5 Phase Angle A R degrees Meter #5 Phase Angle

0434* 1076 Meter #5 Phase-to-Phase Voltage A R V Meter #5 Instantaneous Voltage

0436* 1078 Meter #5 THD Phase B R % Meter #5 Total Harmonic Distortion

0438* 1080 Meter #5 Phase Angle B R degrees Meter #5 Phase Angle

043A* 1082 Meter #5 Phase-to-Phase Voltage B R V Meter #5 Instantaneous Voltage

043C* 1084 Meter #5 THD Phase C R % Meter #5 Total Harmonic Distortion

043E* 1086 Meter #5 Phase Angle C R degrees Meter #5 Phase Angle

0440* 1088 Meter #5 Phase-to-Phase Voltage C R V Meter #5 Instantaneous Voltage

0442* 1090 Meter #6 THD Phase A R % Meter #6 Total Harmonic Distortion

Addr Description R/W Units Notes

0444* 1092 Meter #6 Phase Angle A R degrees Meter #6 Phase Angle

0446* 1094 Meter #6 Phase-to-Phase Voltage A R V Meter #6 Instantaneous Voltage

0448 1096 Meter #6 THD Phase B R % Meter #6 Total Harmonic Distortion

044A* 1098 Meter #6 Phase Angle B R degrees Meter #6 Phase Angle

044C* 1100 Meter #6 Phase-to-Phase Voltage B R V Meter #6 Instantaneous Voltage

044E* 1102 Meter #6 THD Phase C R % Meter #6 Total Harmonic Distortion

0450* 1104 Meter #6 Phase Angle C R degrees Meter #6 Phase Angle

0452* 1106 Meter #6 Phase-to-Phase Voltage C R V Meter #6 Instantaneous Voltage

0454* 1108 Meter #7 THD Phase A R % Meter #7 Total Harmonic Distortion

0456* 1110 Meter #7 Phase Angle A R degrees Meter #7 Phase Angle

0458* 1112 Meter #7 Phase-to-Phase Voltage A R V Meter #7 Instantaneous Voltage

045A* 1114 Meter #7 THD Phase B R % Meter #7 Total Harmonic Distortion

045C* 1116 Meter #7 Phase Angle B R degrees Meter #7 Phase Angle

045E* 1118 Meter #7 Phase-to-Phase Voltage B R V Meter #7 Instantaneous Voltage

0460* 1120 Meter #7 THD Phase C R % Meter #7 Total Harmonic Distortion

0462* 1122 Meter #7 Phase Angle C R degrees Meter #7 Phase Angle

0464* 1124 Meter #7 Phase-to-Phase Voltage C R V Meter #7 Instantaneous Voltage

0466* 1126 Meter #8 THD Phase A R % Meter #8 Total Harmonic Distortion

4–22 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 4: COMMUNICATIONS MODBUS MEMORY MAP

Table 4–1: Modbus Memory Map (Sheet 15 of 15)

Hex

Addr

0468* 1128 Meter #8 Phase Angle A R degrees Meter #8 Phase Angle

046A* 1130 Meter #8 Phase-to-Phase Voltage A R V Meter #8 Instantaneous Voltage

046C* 1132 Meter #8 THD Phase B R % Meter #8 Total Harmonic Distortion

046E* 1134 Meter #8 Phase Angle B R degrees Meter #8 Phase Angle

0470* 1136 Meter #8 Phase-to-Phase Voltage B R V Meter #8 Instantaneous Voltage

0472* 1138 Meter #8 THD Phase C R % Meter #8 Total Harmonic Distortion

0474* 1140 Meter #8 Phase Angle C R degrees Meter #8 Phase Angle

0476* 1142 Meter #8 Phase-to-Phase Voltage C R V Meter #8 Instantaneous Voltage

07D0 2000 Number of phases offset R

07D1 2001 Demand Window Offset R

07D2 2002 I Multiplier Type Offset R

07D3 2003 Number of Pulse Counters Offset R

07D4 2004 Overlap Offset R

Addr Description R/W Units Notes

Counters

16-bit Unsigned Integer 1, 2, 3, or 24 phases available

16-bit Unsigned Integer 5, 15, or 30 minutes available

16-bit Unsigned Integer Internal calibration value

16-bit Unsigned Integer Number of external pulse inputs installed

16-bit Unsigned Integer Number of adjacent demand windows that are averaged to determine peak demand

07D5 2005 Number TOU's Offset R

07D6 2006 MDT_M_TABLE_REG_START R 16-bit Unsigned Integer

07D7 2007 NUM_MDT_M_TABLE_COLUMNS R 16-bit Unsigned Integer

07D8 2008 NUM_MDT_M_TABLE_REGS R 16-bit Unsigned Integer

07D9 2009 MDT_M_TABLE_REG_END R 16-bit Unsigned Integer

16-bit Unsigned Integer Number of different TOU periods defined in the time-ofuse table

* 32-bit floating point register.

32-bit long integer - Range: 00000000h to FFFFFFFFh

Note

1. 32-bit floating point numbers are as per the IEEE 754-1985 standard.

2. Registers 0X0063 to 0X025E are all read-only and cannot be modified. They break down as follows:

• Registers 0X0064 to 0X0122 are not real-time, but are populated with stored interval data based on user inputs to registers 0X0040 to 0X0043.

• Registers 0X0162 to 0X025E are all real-time data registers.

EPM 4500 SUB METER – INSTRUCTION MANUAL 4–23

MODBUS MEMORY MAP CHAPTER 4: COMMUNICATIONS

4–24 EPM 4500 SUB METER – INSTRUCTION MANUAL

GE Energy

Industrial Solutions

709710A1.CDR

Miscellaneous

5.1 Revision History

EPM4500 Sub Meter

Chapter 5: Miscellaneous

5.1.1 Release Dates

GEK-106555 1601-0157-A1 1.0x 10 June 2004

GEK-106555A 1601-0157-A2 1.0x 18 October 2004

GEK-106555B 1601-0157-A3 1.0x 1 December 2004

GEK-106555C 1601-0157-A4 1.0x 5 January 2005

GEK-106555D 1601-0157-A5 1.0x 14 February 2005

GEK-106555E 1601-0157-A6 1.0x 08 April 2005

GEK-106555F 1601-0157-A7 1.0x 20 February 2006

GEK-106555G 1601-0157-A8 1.0x 30 June 2006

GEK-106555H 1601-0157-A9 1.0x 22 November 2007

Table 5–1: Release Dates

MANUAL GE PART NO. EPM4500

REVISION

RELEASE DATE

EPM 4500 SUB METER – INSTRUCTION MANUAL 5–1

REVISION HISTORY CHAPTER 5: MISCELLANEOUS

5.1.2 Changes to the Manual

Table 5–2: Major Updates for 1601-0157-A9

PAGE

(A8)

PAGE

(A9)

CHANGE DESCRIPTION

Title Title Update Manual part number to 1601-0157-A9

4-9 4-9 Update

Modbus Memory Map - inserted hex addresses and notes.

Table 5–3: Major Updates for 1601-0157-A8

PAGE

(A7)

PAGE

(A8)

CHANGE DESCRIPTION

Title Title Update Manual part number to 1601-0157-A8

4-1 4-1 Update Updated RS485 WIRING FOR MODBUS section

--- 4-2 Add Added RS232 WIRING FOR MODBUS section

Table 5–4: Major Updates for 1601-0157-A7

PAGE

(A6)

PAGE

(A7)

CHANGE DESCRIPTION

Title Title Update Manual part number to 1601-0157-A7

3-2 3-2 Update Updated EPM4500 DISPLAY STRUCTURE diagram

Table 5–5: Major Updates for 1601-0157-A6

PAGE

(A5)

PAGE

(A6)

CHANGE DESCRIPTION

Title Title Update Manual part number to 1601-0157-A6

4-3 4-3 Update Updated MODBUS ACTIVATION section

Table 5–6: Major Updates for 1601-0157-A5

PAGE

(A4)

PAGE

(A5)

CHANGE DESCRIPTION

Title Title Update Manual part number to 1601-0157-A5

--- 4-1 Add Added RS485 WIRING FOR MODBUS section

5–2 EPM 4500 SUB METER – INSTRUCTION MANUAL

CHAPTER 5: MISCELLANEOUS REVISION HISTORY

Table 5–7: Major Updates for 1601-0157-A4

PAGE

(A3)

PAGE

(A4)

CHANGE DESCRIPTION

Title Title Update Manual part number to 1601-0157-A4

4-6 4-6 Update

Updated MODBUS MEMORY MAP to include additional registers

Table 5–8: Major Updates for 1601-0157-A3

PAGE

(A2)

PAGE

(A3)

CHANGE DESCRIPTION

Title Title Update Manual part number to 1601-0157-A3

4-3 4-3 Update Updated MODBUS ACTIVATION section

Table 5–9: Major Updates for 1601-0157-A2

PAGE

(A1)

PAGE

(A2)

CHANGE DESCRIPTION

Title Title Update Manual part number to 1601-0157-A2

--- 2-2 Replace

updated PHASE ASSOCIATION section. Phase rotation information is now included with the wiring types.

Replaced PHASE ROTATION section and example with

--- 2-4 Replace

Updated the WIRING section to include new wiring diagrams and wiring procedures

--- 4-1 Add Added MODBUS COMMUNICATIONS chapter

EPM 4500 SUB METER – INSTRUCTION MANUAL 5–3

WARRANTY CHAPTER 5: MISCELLANEOUS

5.2 Warranty

5.2.1 GE Energy Warranty

General Electric Energy (GE Energy) warrants each device it manufactures to be free from defects in material and workmanship under normal use and service for a period of 24 months from date of shipment from factory.

In the event of a failure covered by warranty, GE Energy will undertake to repair or replace the device providing the warrantor determined that it is defective and it is returned with all transportation charges prepaid to an authorized service centre or the factory. Repairs or replacement under warranty will be made without charge.

Warranty shall not apply to any device which has been subject to misuse, negligence, accident, incorrect installation or use not in accordance with instructions nor any unit that has been altered outside a GE Energy authorized factory outlet.

GE Energy is not liable for special, indirect or consequential damages or for loss of profit or for expenses sustained as a result of a device malfunction, incorrect application or adjustment.

For complete text of Warranty (including limitations and disclaimers), refer to GE Energy Standard Conditions of Sale.

5–4 EPM 4500 SUB METER – INSTRUCTION MANUAL

Index

ANSI APPROVAL......................................................................................................................................................1–7

APPLICATIONS.........................................................................................................................................................1–2

CATALOG NUMBERS.............................................................................................................................................1–8

CHANGES TO MANUAL..............................................................................................................................5–2, 5–3

COMMERCIAL METER...........................................................................................................................................1–8

COMMUNICATIONS

activating Modbus communications.................................................................................................4–7

memory map ................................................................................................................................................4–9

Modbus............................................................................................................................................................4–2

Modbus data groups.................................................................................................................................4–3

CT INSTALLATION ............................................................................................................................................... 2–15

CT MULTIPLIERS .....................................................................................................................................................3–4

CT ORDER CODES ..................................................................................................................................................1–9

CURRENT TRANSFORMER INSTALLATION................................................................................................2–15

CURRENT, VERIFYING...........................................................................................................................................3–6

DATA LOGGER.........................................................................................................................................................1–5

DEMAND, RESETTING...........................................................................................................................................3–7

DEMAND, SPECIFICATIONS................................................................................................................................1–5

DIMENSIONS............................................................................................................................................................1–6

DISPLAY STRUCTURE............................................................................................................................................3–3

ENERGY, VERIFYING..............................................................................................................................................3–6

ENVIRONMENTAL SPECIFICATIONS...............................................................................................................1–6

GETTING STARTED.................................................................................................................................................1–1

INSTALLATION CATEGORY.................................................................................................................................1–6

INTERIOR VIEW .......................................................................................................................................................1–3

INTERNAL FUSE BLOCK.................................................................................................................................... 2–17

MCI BOARD, WIRING .........................................................................................................................................2–16

MENU NAVIGATION ..............................................................................................................................................3–1

MENU STRUCTURE................................................................................................................................................3–3

METERING SYSTEM................................................................................................................................................1–2

EPM 4500 SUB METER – INSTRUCTION MANUAL INDEX–1

INDEX

METERING SYSTEM REQUIREMENTS.............................................................................................................2–1

METERING, SPECIFICATIONS.............................................................................................................................1–5

MODBUS

activating........................................................................................................................................................4–7

commands .....................................................................................................................................................4–2

data register groups..................................................................................................................................4–3

memory map ................................................................................................................................................4–9

wiring................................................................................................................................................................4–2

OPTIONS ....................................................................................................................................................................1–8

ORDER CODES.........................................................................................................................................................1–8

POLLUTION DEGREE.............................................................................................................................................1–6

POWER SUPPLY ......................................................................................................................................................1–5

PREVENTIVE MAINTENANCE.............................................................................................................................1–4

PROTECTIVE CONDUCTOR TERMINAL..........................................................................................................1–4

PROTOCOLS..............................................................................................................................................................1–6

PULSE INPUTS .........................................................................................................................................................1–9

RESIDENTIAL METER.............................................................................................................................................1–8

RS232 WIRING FOR MODBUS..........................................................................................................................4–2

RS485 WIRING FOR MODBUS..........................................................................................................................4–1

SCAN TRANSPONDER

functionality...................................................................................................................................................1–2

installing.......................................................................................................................................................2–18

location.........................................................................................................................................................2–18

models..............................................................................................................................................................1–9

SHIPPING SPECIFICATIONS................................................................................................................................1–6

SPECIFICATIONS.....................................................................................................................................................1–5

STAND-ALONE METER .........................................................................................................................................1–2

TRANSIENT/SURGE SUPRESSION....................................................................................................................1–6

TYPE TESTS................................................................................................................................................................1–6

UL APPROVAL..........................................................................................................................................................1–7

USER INTERFACE....................................................................................................................................................3–1

VERIFYING CURRENT............................................................................................................................................3–6

VERIFYING ENERGY...............................................................................................................................................3–6

VERIFYING METER FUNCTIONALITY...............................................................................................................3–5

INDEX–2 EPM 4500 SUB METER – INSTRUCTION MANUAL

VERIFYING VOLTAGE ............................................................................................................................................3–5

VERTICAL MOUNTING OPTION.........................................................................................................................2–2

VOLTAGE, VERIFYING...........................................................................................................................................3–5

WARNINGS ...............................................................................................................................................................1–3

WARRANTY...............................................................................................................................................................5–4

WIRING

1-phase, 3-wire.............................................................................................................................2–12, 2–14

1-phase, 3-wire 120 V..................................................................................................................... 2–6, 2–8

3-phase, 3-wire delta................................................................................................................... 2–9, 2–11

3-phase, 4-wire wye........................................................................................................................2–3, 2–5

overview..........................................................................................................................................................2–2

EPM 4500 SUB METER – INSTRUCTION MANUAL INDEX–3

INDEX

INDEX–4 EPM 4500 SUB METER – INSTRUCTION MANUAL

GE Industrial Solutions EPM4500 User Manual

Specifications and Main Features

Frequently Asked Questions

User Manual

1.1 Getting Started

Overview

1.1.1 Description

1.2 Applications

1.2.1 Stand-Alone Meter

1.2.2 Metering System

1.2.3 Interior View

1.2.4 Cautions and Warnings

1.2.5 Protective Conductor Terminal

1.2.6 Preventive Maintenance

1.3 Specifications

1.3.1 Monitoring

1.3.2 Power Supply

1.3.3 Metering

1.3.4 Inputs

1.3.5 Communications

1.3.6 Physical

1.3.7 Type Tests and Approvals

1.4 Ordering

Family Back Box Voltage Options Description

1.4.2 EPM 4500 Residential

1.4.5 Current Transformers (0.1 A Secondary)

1.4.6 Transponder Models

1.4.7 Pulse Inputs

2.1 Getting Ready

Installation

2.1.1 Determination of Metering System Requirements

2.1.2 Phase Association

2.2 Wiring

2.2.1 Overview of Meter Wiring

2.2.2 Wiring Overview

2.2.3 Three-Phase Four-Wire Wye Wiring

2.2.4 Single-Phase, Three-Wire 120 V Wiring

2.2.5 Three-Phase, Three-Wire Delta Wiring

2.2.6 Single-Phase, Three-Wire Wiring

2.3 Installation of Meter, MCI Board, and CTs

2.3.1 Procedure

2.4 Installing the Scan Transponder

2.4.1 Procedure

Using the Meter

3.1 Menu Navigation

3.1.1 User Interface

3.2 CT Multiplier Table

3.2.1 CT Multipliers

3.3 Verifying Meter Functionality

3.3.1 Overview

3.3.2 Verifying Voltage

3.3.3 Verifying kWh Reading

3.3.4 Verifying Current and Energy

3.4 Resetting the Demand Values

3.4.1 Procedure

Communications

4.1 Modbus Communications

4.1.1 RS485 Wiring for Modbus

4.1.2 RS232 Wiring for Modbus

4.1.3 Modbus Commands

4.1.4 Fixed Modbus Values

4.1.5 Modbus Data Register (R4 Type) Groups

4.1.6 Instantaneous Data Items

4.1.7 32-bit Long and Float Data Formats

4.2 Modbus Activation

4.2.1 Overview

4.2.2 Configuring a New HyperTerminal Session

4.2.3 Confirming Connection to the EPM4500

4.2.4 Logging into the Meter

4.2.5 Activating Modbus Communications

4.2.6 Changing Modbus Settings

4.2.7 Logging Out

4.2.8 Disabling Modbus Communications

4.3 Modbus Memory Map

4.3.1 Memory Map

Miscellaneous

5.1 Revision History

5.1.1 Release Dates

5.1.2 Changes to the Manual

5.2 Warranty