GE Consumer & Industrial
Multilin
EPM 6000
Instruction Manual
Software Revision: 4.5
Manual P/N: 1601-0215-A4
Manual Order Code: GEK-106558C
Copyright © 2007 GE Multilin
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GE Multilin
ISO9001:2000
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215 Anderson Avenue, Markham, Ontario
Canada L6E 1B3
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GE Multilin's Quality
Management System is
registered to ISO9001:2000
Tel: (905) 294-6222 Fax: (905) 201-2098
Internet: http://www.GEmultilin.com
QMI # 005094
LISTED
*1601-0215-A4*
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Table of Contents
1: OVERVIEW
INTRODUCTION ................................................................................................................................ 1-1
DESCRIPTION ........................................................................................................................ 1-1
HIGHLIGHTS ......................................................................................................................... 1-1
FEATURES ............................................................................................................................................ 1-3
UNIVERSAL VOLTAGE INPUTS ............................................................................................ 1-3
CURRENT INPUTS ................................................................................................................. 1-3
UTILITY PEAK DEMAND ....................................................................................................... 1-3
MEASURED VALUES ............................................................................................................ 1-4
ORDERING ........................................................................................................................................... 1-5
ORDER CODES ..................................................................................................................... 1-5
SPECIFICATIONS ............................................................................................................................... 1-6
INPUTS/OUTPUTS ................................................................................................................ 1-6
METERING ............................................................................................................................. 1-6
ENVIRONMENTAL ................................................................................................................. 1-7
COMMUNICATIONS .............................................................................................................. 1-7
MECHANICAL PARAMETERS ................................................................................................ 1-7
APPROVALS ........................................................................................................................... 1-8
2: ELECTRICAL
BACKGROUND
THREE-PHASE POWER MEASUREMENT ................................................................................. 2-1
DESCRIPTION ........................................................................................................................ 2-1
THREE-PHASE SYSTEM CONFIGURATIONS ........................................................................... 2-2
DESCRIPTION ........................................................................................................................ 2-2
WYE CONNECTION .............................................................................................................. 2-2
DELTA CONNECTION ........................................................................................................... 2-4
BLONDELL'S THEOREM AND THREE-PHASE MEASUREMENT ........................................ 2-5
POWER, ENERGY, AND DEMAND .............................................................................................. 2-8
DESCRIPTION ........................................................................................................................ 2-8
POWER .................................................................................................................................. 2-8
ENERGY ................................................................................................................................. 2-8
DEMAND ............................................................................................................................... 2-10
REACTIVE ENERGY AND POWER FACTOR ............................................................................. 2-12
REAL, REACTIVE, AND APPARENT POWER ........................................................................ 2-12
POWER FACTOR ................................................................................................................... 2-13
HARMONIC DISTORTION .............................................................................................................. 2-14
HARMONICS OF A NON-SINUSOIDAL WAVEFORM ......................................................... 2-14
INDUCTIVE AND CAPACITIVE IMPEDANCE ......................................................................... 2-15
VOLTAGE AND CURRENT MONITORING ............................................................................ 2-15
WAVEFORM CAPTURE ......................................................................................................... 2-16
POWER QUALITY .............................................................................................................................. 2-17
DESCRIPTION ........................................................................................................................ 2-17
3: INSTALLATION
MECHANICAL INSTALLATION ..................................................................................................... 3-1
DIMENSIONS ......................................................................................................................... 3-1
ANSI INSTALLATION STEPS ............................................................................................... 3-2
DIN INSTALLATION STEPS .................................................................................................. 3-3
ELECTRICAL INSTALLATION ......................................................................................................... 3-5
EPM 6000 MULTI-FUNCTION POWER METERING SYSTEM – USER GUIDE
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INSTALLATION CONSIDERATIONS ....................................................................................... 3-5
CT LEADS TERMINATED TO METER ................................................................................... 3-6
CT LEADS PASS-THROUGH (NO METER TERMINATION) ................................................ 3-6
QUICK CONNECT CRIMP CT TERMINATIONS ................................................................... 3-7
VOLTAGE AND POWER SUPPLY CONNECTIONS .............................................................. 3-7
GROUND CONNECTIONS .................................................................................................... 3-8
WIRING DIAGRAMS ......................................................................................................................... 3-9
DESCRIPTION ........................................................................................................................ 3-9
WYE, 4-WIRE WITH NO PTS AND 3 CTS, 3 ELEMENT .................................................. 3-10
WYE, 4-WIRE WITH NO PTS AND 3 CTS, 2.5 ELEMENT .............................................. 3-11
WYE, 4-WIRE WITH 3 PTS AND 3 CTS, 3 ELEMENT .................................................... 3-12
WYE, 4-WIRE WITH 2 PTS AND 3 CTS, 2.5 ELEMENT ................................................. 3-13
DELTA, 3-WIRE WITH NO PTS AND 2 CTS ..................................................................... 3-14
DELTA, 3-WIRE WITH 2 PTS AND 2 CTS ........................................................................ 3-15
CURRENT-ONLY MEASUREMENT (THREE-PHASE) ..........................................................3-16
CURRENT-ONLY MEASUREMENT (DUAL-PHASE) ............................................................3-17
CURRENT-ONLY MEASUREMENT (SINGLE-PHASE) ......................................................... 3-18
COMMUNICATIONS SETUP .......................................................................................................... 3-19
DESCRIPTION ........................................................................................................................ 3-19
IRDA COM1 PORT ............................................................................................................. 3-19
RS485 COM2 PORT ......................................................................................................... 3-19
4: USING THE METER
FRONT PANEL INTERFACE ............................................................................................................ 4-1
DESCRIPTION ........................................................................................................................ 4-1
FACEPLATE ELEMENTS ........................................................................................................ 4-1
FACEPLATE BUTTONS .......................................................................................................... 4-2
PERCENTAGE OF LOAD BAR ............................................................................................... 4-3
WATT-HOUR ACCURACY TESTING (VERIFICATION) ........................................................ 4-4
CONFIGURING THE METER VIA THE FRONT PANEL ..........................................................4-5
OVERVIEW ............................................................................................................................ 4-5
START UP .............................................................................................................................. 4-5
MAIN MENU ......................................................................................................................... 4-6
RESET MODE AND PASSWORD ENTRY ............................................................................. 4-6
CHANGING SETTINGS IN CONFIGURATION MODE ...........................................................4-9
DESCRIPTION ........................................................................................................................ 4-9
CONFIGURING THE SCROLL FEATURE ............................................................................... 4-9
PROGRAMMING THE CONFIGURATION MODE SCREENS ................................................ 4-10
CONFIGURING THE CT SETTING ........................................................................................ 4-11
CONFIGURING THE PT SETTING ........................................................................................ 4-12
CONFIGURING THE CONNECTION SETTING ...................................................................... 4-13
CONFIGURING THE COMMUNICATION PORT SETTING .................................................... 4-14
OPERATING MODE ........................................................................................................................... 4-17
DESCRIPTION ........................................................................................................................ 4-17
5: COMMUNICATIONS
MODBUS COMMUNICATIONS ..................................................................................................... 5-1
MEMORY MAP DESCRIPTION ............................................................................................. 5-1
MEMORY MAP ......................................................................................................................5-1
MODBUS MEMORY MAP NOTES ....................................................................................... 5-7
MODBUS MEMORY MAP DATA FORMATS ........................................................................ 5-9
DNP POINT MAPPING ..................................................................................................................... 5-10
DNP POINT MAPS .............................................................................................................. 5-10
DNP POINT MAP NOTES ................................................................................................... 5-12
TOC–2
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DNP IMPLEMENTATION ................................................................................................................. 5-13
OVERVIEW ............................................................................................................................ 5-13
DATA LINK LAYER ................................................................................................................ 5-13
TRANSPORT LAYER .............................................................................................................. 5-13
APPLICATION LAYER ............................................................................................................ 5-14
DNP OBJECTS AND VARIATIONS ............................................................................................... 5-15
DESCRIPTION ........................................................................................................................ 5-15
BINARY OUTPUT STATUS (OBJECT 10, VARIATION 2) ................................................... 5-15
CONTROL RELAY OUTPUT (OBJECT 12, VARIATION 1) .................................................. 5-15
32-BIT BINARY COUNTER WITHOUT FLAG (OBJECT 20, VARIATION 4) .................... 5-16
16-BIT ANALOG INPUT WITHOUT FLAG (OBJECT 30, VARIATION 5) ......................... 5-16
CLASS 0 DATA (OBJECT 60, VARIATION 1) ..................................................................... 5-17
INTERNAL INDICATIONS (OBJECT 80, VARIATION 1) ...................................................... 5-17
6: MISCELLANEOUS
NAVIGATION MAPS ......................................................................................................................... 6-1
INTRODUCTION ..................................................................................................................... 6-1
MAIN MENU SCREENS ........................................................................................................ 6-2
OPERATING MODE SCREENS ............................................................................................. 6-3
RESET MODE SCREENS ....................................................................................................... 6-4
CONFIGURATION MODE SCREENS .................................................................................... 6-5
REVISION HISTORY .......................................................................................................................... 6-6
RELEASE DATES ................................................................................................................... 6-6
CHANGES TO THE MANUAL ............................................................................................... 6-6
WARRANTY ......................................................................................................................................... 6-8
GE MULTILIN WARRANTY .................................................................................................. 6-8
EPM 6000 MULTI-FUNCTION POWER METERING SYSTEM – USER GUIDE
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EPM 6000 MULTI-FUNCTION POWER METERING SYSTEM – USER GUIDE
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GE Consumer & Industrial
Multilin
EPM 6000 Multi-function Power
Metering System
Chapter 1: Overview
Overview
1.1 Introduction
1.1.1 Description
The EPM 6000 is a multifunction power meter designed to be used in electrical substations,
panel boards and as a power meter for OEM equipment. The unit provides multifunction
measurement of electrical parameters.
The unit is designed with advanced measurement capabilities, allowing it to achieve high
performance accuracy. The EPM 6000 is specified as a 0.2% class energy meter for billing
applications as well as a highly accurate panel indication meter.
The EPM 6000 provides a host of additional capabilities, including standard RS485 Modbus
Protocol and an IrDA port remote interrogation.
1.1.2 Highlights
The following EPM 6000 features are detailed in this manual:
•
•
•
•
•
•
•
0.2% class revenue certifiable energy and demand metering
Meets ANSI C12.20 (0.2%) and IEC 687 (0.2%) classes
Multifunction measurement including voltage, current, power, frequency, energy
Percentage of load bar for analog meter perception
Easy-to-use faceplate programming
IrDA port for PDA remote read
RS485 Modbus communications
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CHAPTER 1: OVERVIEW
FIGURE 1–1: EPM 6000 Highlights
1–2
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CHAPTER 1: OVERVIEW
1.2 Features
1.2.1 Universal Voltage Inputs
Voltage Inputs allow measurement to 416 V line-to-neutral and 721 V line-to-line. This
insures proper meter safety when wiring directly to high voltage systems. One unit will
perform to specification on 69 V, 120 V, 230 V, 277 V, and 347 V systems.
1.2.2 Current Inputs
The EPM 6000 current inputs use a unique dual input method.
•
Method 1 – CT Pass Through: The CT passes directly through the meter without
any physical termination on the meter. This insures that the meter cannot be a
point of failure on the CT circuit. This is preferable for utility users when sharing
relay class CTs. No burden is added to the secondary CT circuit.
•
Method 2 – Current “Gills”: This unit additionally provides ultra-rugged
termination pass-through bars that allow CT leads to be terminated on the meter.
This, too, eliminates any possible point of failure at the meter. This is a preferred
technique for insuring that relay class CT integrity is not compromised (the CT will
not open in a fault condition).
FIGURE 1–2: Current Input Connections
1.2.3 Utility Peak Demand
The EPM 6000 provides user-configured Block (fixed) or Rolling window demand. This
feature allows you to set up a customized demand profile. Block window demand is
demand used over a user-defined demand period (usually 5, 15, or 30 minutes). Rolling
window demand is a fixed window demand that moves for a user-specified subinterval
period. For example, a 15-minute demand using 3 subintervals and providing a new
demand reading every 5 minutes, based on the last 15 minutes.
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CHAPTER 1: OVERVIEW
Utility demand features can be used to calculate kW, kvar, kVA and PF readings. All other
parameters offer maximum and minimum capability over the user-selectable averaging
period. Voltage provides an instantaneous maximum and minimum reading which
displays the highest surge and lowest sag seen by the meter.
1.2.4 Measured Values
The EPM 6000 provides the following measured values all in real time and some
additionally as average, maximum, and minimum values.
Table 1–1: EPM 6000 Measured Values
Measured Values
Voltage L-N
Real Time
Average
Maximum
Minimum
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Voltage L-L
Current per phase
Watts
X
X
X
X
X
vars
VA
Power Factor (PF)
Positive watt-hours
Negative watt-hours
Net watt-hours
Positive var-hours
Negative var-hours
Net var-hours
VA-hours
Frequency
X
X
X
X
%THD
Voltage angles
Current angles
% of load bar
1–4
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CHAPTER 1: OVERVIEW
1.3 Ordering
1.3.1 Order Codes
The order codes for the EPM 6000 are indicated below.
Table 1–2: EPM 6000 Order Codes
PL6000
–
*
|
–
*
|
–
*
Base Unit
EPM 6000 Power Metering System
50 Hz AC frequency system
60 Hz AC frequency system
1 A secondary CT
PL6000
|
5
6
|
|
|
|
|
|
System
Frequency
1A
5A
Current Input
5 A secondary CT
No THD or pulse output option
THD, limit alarms, and 1 KYZ pulse output
0
THD
THD and Pulse Output
For example, to order an EPM 6000 for 60 Hz system with a 1 A secondary CT input and no
THD or pulse output option, select order code PL6000-6-1A-0. The standard unit includes
display, all current/voltage/power/frequency/energy counters, percent load bar, RS485,
and IrDA communication ports.
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CHAPTER 1: OVERVIEW
1.4 Specifications
1.4.1 Inputs/Outputs
POWER SUPPLY
Range:..................................................................D2 Option: Universal, 90 to 265 V AC at 50/60Hz, or 100 to
370 V DC
D Option: 18 to 60 V DC
Power consumption:.....................................5 VA, 3.5 W
VOLTAGE INPUTS (MEASUREMENT CATEGORY III)
Range:..................................................................Universal, Auto-ranging up to 416 V AC L-N, 721 V AC L-L
Supported hookups:......................................3-element Wye, 2.5-element Wye, 2-element Delta,
4-wire Delta
Input impedance: ...........................................1 MOhm/phase
Burden:................................................................0.0144 VA/phase at 120 Volts
Pickup voltage: ................................................10 V AC
Connection:.......................................................Screw terminal (see Voltage Connection on page 3–8)
2
Maximum input wire gauge: ....................AWG #12 / 2.5 mm
Fault withstand: ..............................................Meets IEEE C37.90.1
Reading:..............................................................Programmable full-scale to any PT ratio
CURRENT INPUTS
Class 10:..............................................................5 A nominal, 10 A maximum
Class 2: ................................................................1 A nominal, 2 A maximum
Burden:................................................................0.005 VA per phase maximum at 11 A
Pickup current:.................................................0.1% of nominal
Connections:.....................................................O or U lug (see CT Leads Terminated to Meter on page 3–
6);
Pass-through wire, 0.177" / 4.5 mm maximum diameter
(see Pass-Through Wire Electrical Connection on page
3–7);
Quick connect, 0.25" male tab
(see Quick Connect Electrical Connection on page 3–7)
Fault Withstand:..............................................100 A / 10 seconds, 300 A / 3 seconds, 500 A / 1 second
Reading:..............................................................Programmable full-scale to any CT ratio
1.4.2 Metering
MEASUREMENT METHODS
Voltage and current:.....................................true RMS
Power:..................................................................sampling at 400+ samples/cycle on all channels
measured; readings simultaneously
A/D conversion:...............................................6 simultaneous 24-bit analog-to-digital converters
UPDATE RATE
Watts, vars, and VA: ......................................100 ms (10 times per second)
All other parameters:....................................1 second
1–6
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CHAPTER 1: OVERVIEW
ACCURACY
Measured Parameters
Voltage L-N
Voltage L-L
Current
Display Range
0 to 9999 kV or scalable
0 to 9999 V or kV scalable
0 to 9999 A or kA
Accuracy
0.1% of reading
0.1% of reading
0.1% of reading
0.2% of reading
0.2% of reading
0.2% of reading
0.2% of reading
0.2% of reading
0.2% of reading
0.2% of reading
0.01 Hz
+/– Watts
+/– Wh
0 to 9999 W, kW, or MW
5 to 8 digits (programmable)
0 to 9999 vars, kvars, Mvars
5 to 8 digits (programmable)
0 to 9999 VA, kVA, MVA
5 to 8 digits (programmable)
±0.5 to 1.0
+/– vars
+/– varh
VA
VAh
Power Factor (PF)
Frequency
% THD
45 to 65 Hz
0 to 100%
2.0% F.S.
% Load Bar
10 digit resolution scalable
1 to 120% of reading
NOTE: Typical results are more accurate.
1.4.3 Environmental
TEMPERATURE AND HUMIDITY
Storage:...............................................................–40 to 85°C
Operating:..........................................................–30 to 70°C
Humidity:............................................................up to 95% RH, non-condensing
Faceplate rating: ............................................NEMA 12 (water resistant), mounting gasket included
1.4.4 Communications
COMMUNICATIONS FORMAT
Types:...................................................................RS485 port through back plate
IrDA port through face plate
COMMUNICATIONS PORTS
Protocol:..............................................................Modbus RTU, Modbus ASCII, DNP 3.0
Baud rate: ..........................................................9600 to 57600 bps
Port address: ....................................................001 to 247
Data format:.....................................................8 bits, no parity
1.4.5 Mechanical Parameters
DIMENSIONS
Size:.......................................................................4.25" × 4.82" × 4.85" (L × W × H)
105.4 mm × 123.2 mm × 123.2 mm (L × W × H)
Mounting:...........................................................mounts in 92 mm square DIN or ANSI C39.1 4-inch round
cut-out
Weight:................................................................2 pounds / 0.907 kg
Shipping..............................................................ships in 6-inch / 152.4 mm cube container
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CHAPTER 1: OVERVIEW
1.4.6 Approvals
TYPE TESTING
IEC 687 (0.2% accuracy)
ANSI C12.20 (0.2% accuracy)
ANSI (IEEE) C37.90.1: ....................................Surge Withstand
ANSI C62.41 (burst)
IEC 1999-4-2: ...................................................ESD
IEC 1000-4-3: ...................................................Radiated Immunity
IEC 1000-4-4: ...................................................Fast Transient
IEC 1000-4-5: ...................................................Surge Immunity
COMPLIANCE
ISO:........................................................................manufactured to an ISO9001 registered program
UL:..........................................................................UL listed (file E250818)
CSA:.......................................................................Certified per: C22.2 No.1010.1 Electrical and Electronic
Measuring and Testing Equipment
CE:..........................................................................conforms to EN 55011 / EN 50082
1–8
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GE Consumer & Industrial
Multilin
EPM 6000 Multi-function Power
Metering System
Chapter 2: Electrical Background
Electrical Background
2.1 Three-Phase Power Measurement
2.1.1 Description
This introduction to three-phase power and power measurement is intended to provide
only a brief overview of the subject. The professional meter engineer or meter technician
should refer to more advanced documents such as the EEI Handbook for Electricity
Metering and the application standards for more in-depth and technical coverage of the
subject.
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CHAPTER 2: ELECTRICAL BACKGROUND
2.2 Three-Phase System Configurations
2.2.1 Description
Three-phase power is most commonly used in situations where large amounts of power
will be used because it is a more effective way to transmit the power and because it
provides a smoother delivery of power to the end load. There are two commonly used
connections for three-phase power, a wye connection or a delta connection. Each
connection has several different manifestations in actual use. When attempting to
determine the type of connection in use, it is a good practice to follow the circuit back to
the transformer that is serving the circuit. It is often not possible to conclusively determine
the correct circuit connection simply by counting the wires in the service or checking
voltages. Checking the transformer connection will provide conclusive evidence of the
circuit connection and the relationships between the phase voltages and ground.
2.2.2 Wye Connection
The wye connection is so called because when you look at the phase relationships and the
winding relationships between the phases it looks like a wye (Y). The following figure
depicts the winding relationships for a wye-connected service. In a wye service the neutral
(or center point of the wye) is typically grounded. This leads to common voltages of 208/
120 and 480/277 (where the first number represents the phase-to-phase voltage and the
second number represents the phase-to-ground voltage).
Ia
A
Van
Vcn
Vbn
B
C
N
FIGURE 2–1: Three-Phase Wye Winding
The three voltages are electrically separated by 120°. Under balanced load conditions with
unity power factor, the currents are also separated by 120°. However, unbalanced loads
and other conditions can cause the currents to depart from the ideal 120° separation.
Three-phase voltages and currents are usually represented with a phasor diagram. A
phasor diagram for the typical connected voltages and currents is shown below.
2–2
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CHAPTER 2: ELECTRICAL BACKGROUND
Vcn
Ic
Van
Ia
Ib
Vbn
FIGURE 2–2: Three-Phase Voltage and Current Phasors for Wye Winding
The phasor diagram shows the 120° angular separation between the phase voltages. The
phase-to-phase voltage in a balanced three-phase wye system is 1.732 times the phase-
to-neutral voltage. The center point of the wye is tied together and is typically grounded.
The following table indicates the common voltages used in the United States for wye-
connected systems.
Table 2–1: Common Phase Voltages on Wye Services
Phase-to-Ground Voltage
120 volts
Phase-to-Phase Voltage
208 volts
277 volts
480 volts
2400 volts
7200 volts
7620 volts
4160 volts
12470 volts
13200 volts
Usually, a wye-connected service will have four wires: three wires for the phases and one
for the neutral. The three-phase wires connect to the three phases. The neutral wire is
typically tied to the ground or center point of the wye (refer to the Three-Phase Wye
Winding diagram above).
In many industrial applications the facility will be fed with a four-wire wye service but only
three wires will be run to individual loads. The load is then often referred to as a delta-
connected load but the service to the facility is still a wye service; it contains four wires if
you trace the circuit back to its source (usually a transformer). In this type of connection
the phase to ground voltage will be the phase-to-ground voltage indicated in the table
above, even though a neutral or ground wire is not physically present at the load. The
transformer is the best place to determine the circuit connection type because this is a
location where the voltage reference to ground can be conclusively identified.
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CHAPTER 2: ELECTRICAL BACKGROUND
2.2.3 Delta Connection
Delta connected services may be fed with either three wires or four wires. In a three-phase
delta service the load windings are connected from phase-to-phase rather than from
phase-to-ground. The following figure shows the physical load connections for a delta
service.
Ia
A
Iab
Vab
Ib
Vca
Ica
B
Vbc
Ibc
Ic
C
FIGURE 2–3: Three-Phase Delta Winding Relationship
In this example of a delta service, three wires will transmit the power to the load. In a true
delta service, the phase-to-ground voltage will usually not be balanced because the
ground is not at the center of the delta.
The following diagram shows the phasor relationships between voltage and current on a
three-phase delta circuit.
In many delta services, one corner of the delta is grounded. This means the phase to
ground voltage will be zero for one phase and will be full phase-to-phase voltage for the
other two phases. This is done for protective purposes.
Vca
Ic
Vbc
Ia
Ib
Vab
FIGURE 2–4: Three-Phase Voltage and Current Phasors for Delta Winding
2–4
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CHAPTER 2: ELECTRICAL BACKGROUND
Another common delta connection is the four-wire, grounded delta used for lighting loads.
In this connection the center point of one winding is grounded. On a 120/240 volt, four-
wire, grounded delta service the phase-to-ground voltage would be 120 volts on two
phases and 208 volts on the third phase. The phasor diagram for the voltages in a three-
phase, four-wire delta system is shown below.
Vca
120 V
Vnc
Vbn
Vbc
120 V
Vab
FIGURE 2–5: Three-Phase, Four-Wire Delta Phasors
2.2.4 Blondell's Theorem and Three-Phase Measurement
In 1893 an engineer and mathematician named Andre E. Blondell set forth the first
scientific basis for poly phase metering. His theorem states:
If energy is supplied to any system of conductors through N wires, the total power in the
system is given by the algebraic sum of the readings of N watt-meters so arranged that
each of the N wires contains one current coil, the corresponding potential coil being
connected between that wire and some common point. If this common point is on one
of the N wires, the measurement may be made by the use of N-1 wattmeters.
The theorem may be stated more simply, in modern language:
In a system of N conductors, N – 1 meter elements will measure the power or energy
taken provided that all the potential coils have a common tie to the conductor in which
there is no current coil.
Three-phase power measurement is accomplished by measuring the three individual
phases and adding them together to obtain the total three phase value. In older analog
meters, this measurement was made using up to three separate elements. Each element
combined the single-phase voltage and current to produce a torque on the meter disk. All
three elements were arranged around the disk so that the disk was subjected to the
combined torque of the three elements. As a result the disk would turn at a higher speed
and register power supplied by each of the three wires.
According to Blondell's Theorem, it was possible to reduce the number of elements under
certain conditions. For example, a three-phase, three-wire delta system could be correctly
measured with two elements (two potential coils and two current coils) if the potential coils
were connected between the three phases with one phase in common.
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In a three-phase, four-wire wye system it is necessary to use three elements. Three voltage
coils are connected between the three phases and the common neutral conductor. A
current coil is required in each of the three phases.
In modern digital meters, Blondell's Theorem is still applied to obtain proper metering. The
difference in modern meters is that the digital meter measures each phase voltage and
current and calculates the single-phase power for each phase. The meter then sums the
three phase powers to a single three-phase reading.
Some digital meters calculate the individual phase power values one phase at a time. This
means the meter samples the voltage and current on one phase and calculates a power
value. Then it samples the second phase and calculates the power for the second phase.
Finally, it samples the third phase and calculates that phase power. After sampling all three
phases, the meter combines the three readings to create the equivalent three-phase
power value. Using mathematical averaging techniques, this method can derive a quite
accurate measurement of three-phase power.
More advanced meters actually sample all three phases of voltage and current
simultaneously and calculate the individual phase and three-phase power values. The
advantage of simultaneous sampling is the reduction of error introduced due to the
difference in time when the samples were taken.
Blondell's Theorem is a derivation that results from Kirchhoff's Law. Kirchhoff's Law states
that the sum of the currents into a node is zero. Another way of stating the same thing is
that the current into a node (connection point) must equal the current out of the node. The
law can be applied to measuring three-phase loads. The figure below shows a typical
connection of a three-phase load applied to a three-phase, four-wire service. Kirchhoff's
Laws hold that the sum of currents A, B, C and N must equal zero or that the sum of
currents into Node “n” must equal zero.
C
B
Phase B
Phase C
Node "n"
Phase A
A
N
FIGURE 2–6: Three-Phase Load Illustrating Kirchhoff’s Law and Blondell’s Theorem
2–6
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If we measure the currents in wires A, B and C, we then know the current in wire N by
Kirchhoff's Law and it is not necessary to measure it. This fact leads us to the conclusion of
Blondell's Theorem that we only need to measure the power in three of the four wires if
they are connected by a common node. In the circuit of Figure 1.6 we must measure the
power flow in three wires. This will require three voltage coils and three current coils (a
three element meter). Similar figures and conclusions could be reached for other circuit
configurations involving delta-connected loads.
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2.3 Power, Energy, and Demand
2.3.1 Description
It is quite common to exchange power, energy, and demand without differentiating
between the three. Because this practice can lead to confusion, the differences between
these three measurements will be discussed.
2.3.2 Power
Power is an instantaneous reading. The power reading provided by a meter is the present
flow of watts. Power is measured immediately just like current. In many digital meters, the
power value is actually measured and calculated over a one-second interval, since it takes
some amount of time to calculate the RMS values of voltage and current. However, this
time interval is kept small to preserve the instantaneous nature of power.
2.3.3 Energy
Energy is always based upon some time increment – it is the integration of power over a
defined time increment. Energy is an important value because almost all electric bills are
based, in part, on the amount of energy consumed.
Typically, electrical energy is measured in units of kilowatt-hours (kWh). A kilowatt-hour
represents a constant load of 1000 watts (1 kW) for 1 hour. Stated another way, if the
power delivered (instantaneous watts) is measured as 1000 W, and the load was served for
a one-hour time interval, then the load would have absorbed 1 kWh of energy. A different
load may have a constant power requirement of 4000 W. If this load were served for one
hour, it would absorb 4 kWh of energy. Likewise, if it were served for 15 minutes, it would
absorb ¼ of that total, or 1 kWh.
The following figure shows a graph of power and the resulting energy that would be
transmitted as a result of the illustrated power values. For this illustration, it is assumed
that the power level is held constant for each minute when a measurement is taken. Each
bar in the graph represents the power load for the one-minute increment of time. In real
life, the power values are continually moving.
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80
70
60
50
40
30
20
10
0
1
2
3
4
5
6
7
8
9
10 11 12 13 14 15
Time (minutes)
FIGURE 2–7: Power Use Over Time
The data in the above figure is reproduced in the following table to illustrate the
calculation of energy. Since the time increment of the measurement is one minute, and
since we specified a constant load over that minute, the power reading can be converted
to an equivalent consumed energy reading by multiplying the power reading by 1/60
(converting the time base from minutes to hours).
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Table 2–2: Power and Energy Relationship Over Time
Time Interval
Power
Energy
Accumulated
Energy
1 minute
30 kW
50 kW
40 kW
55 kW
60 kW
60 kW
70 kW
70 kW
60 kW
70 kW
80 kW
50 kW
50 kW
70 kW
80 kW
0.50 kWh
0.83 kWh
0.67 kWh
0.92 kWh
1.00 kWh
1.00 kWh
1.17 kWh
1.17 kWh
1.00 kWh
1.17 kWh
1.33 kWh
0.83 kWh
0.83 kWh
1.17 kWh
1.33 kWh
0.50 kWh
1.33 kWh
2.00 kWh
2.92 kWh
3.92 kWh
4.92 kWh
6.09 kWh
7.26 kWh
8.26 kWh
9.43 kWh
10.76 kWh
12.42 kWh
12.42 kWh
13.59 kWh
14.92 kWh
2 minutes
3 minutes
4 minutes
5 minutes
6 minutes
7 minutes
8 minutes
9 minutes
10 minutes
11 minutes
12 minutes
13 minutes
14 minutes
15 minutes
As shown in the above table, the accumulated energy for the power load profile of the
data in Power Use Over Time on page 2–9 is 14.92 kWh.
2.3.4 Demand
Demand is also a time-based value. The demand is the average rate of energy use over
time. The actual label for demand is kilowatt-hours/hour but this is normally reduced to
kilowatts. This makes it easy to confuse demand with power. But demand is not an
instantaneous value. To calculate demand it is necessary to accumulate the energy
readings (as illustrated in Power Use Over Time on page 2–9) and adjust the energy reading
to an hourly value that constitutes the demand.
In the example, the accumulated energy is 14.92 kWh. But this measurement was made
over a 15-minute interval. To convert the reading to a demand value, it must be
normalized to a 60-minute interval. If the pattern were repeated for an additional three 15-
minute intervals the total energy would be four times the measured value or 59.68 kWh.
The same process is applied to calculate the 15-minute demand value. The demand value
associated with the example load is 59.68 kWh/hour or 59.68 kWd. Note that the peak
instantaneous value of power is 80 kW, significantly more than the demand value.
2–10
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The following figure illustrates another example of energy and demand. In this case, each
bar represents the energy consumed in a 15-minute interval. The energy use in each
interval typically falls between 50 and 70 kWh. However, during two intervals the energy
rises sharply and peaks at 100 kWh in interval #7. This peak of usage will result in setting a
high demand reading. For each interval shown the demand value would be four times the
indicated energy reading. So interval 1 would have an associated demand of 240 kWh/hr.
Interval #7 will have a demand value of 400 kWh/hr. In the data shown, this is the peak
demand value and would be the number that would set the demand charge on the utility
bill.
100
80
60
40
20
0
1
2
3
4
5
6
7
8
Intervals (15 mins.)
FIGURE 2–8: Energy Use and Demand Intervals
As seen in this example, it is important to recognize the relationships between power,
energy and demand in order to effectively control loads or to correctly monitor use.
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2.4 Reactive Energy and Power Factor
2.4.1 Real, Reactive, and Apparent Power
The real power and energy measurements discussed in the previous section relate to the
quantities that are most used in electrical systems. But it is often not sufficient to only
measure real power and energy. Reactive power is a critical component of the total power
picture because almost all real-life applications have an impact on reactive power.
Reactive power and power factor concepts relate to both load and generation
applications. However, this discussion will be limited to analysis of reactive power and
power factor as they relate to loads. To simplify the discussion, generation will not be
considered.
Real power (and energy) is the component of power that is the combination of the voltage
and the value of corresponding current that is directly in phase with the voltage. However,
in actual practice the total current is almost never in phase with the voltage. Since the
current is not in phase with the voltage, it is necessary to consider both the in-phase
component and the component that is at quadrature (angularly rotated 90° or
perpendicular) to the voltage. The following figure shows a single-phase voltage and
current and breaks the current into its in-phase and quadrature components.
IR
V
θ
IX
I
FIGURE 2–9: Voltage and Complex Current
The voltage (V) and the total current (I) can be combined to calculate the apparent power
or VA. The voltage and the in-phase current (IR) are combined to produce the real power or
watts. The voltage and the quadrature current (IX) are combined to calculate the reactive
power.
The quadrature current may be lagging the voltage (as shown above) or it may lead the
voltage. When the quadrature current lags the voltage the load is requiring both real
power (watts) and reactive power (vars). When the quadrature current leads the voltage
the load is requiring real power (watts) but is delivering reactive power (vars) back into the
system; that is VARs are flowing in the opposite direction of the real power flow.
Reactive power (vars) is required in all power systems. Any equipment that uses
magnetization to operate requires vars. Usually the magnitude of vars is relatively low
compared to the real power quantities. Utilities have an interest in maintaining VAR
requirements at the customer to a low value in order to maximize the return on plant
invested to deliver energy. When lines are carrying vars, they cannot carry as many watts.
2–12
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So keeping the var content low allows a line to carry its full capacity of watts. In order to
encourage customers to keep VAR requirements low, most utilities impose a penalty if the
var content of the load rises above a specified value.
2.4.2 Power Factor
A common method of measuring reactive power requirements is power factor. Power
factor can be defined in two different ways. The more common method of calculating
power factor is the ratio of the real power to the apparent power. This relationship is
expressed in the following formula:
real power
apparent power VA
watts
Total PF = ---------------------------------------- = -------------
(EQ 2.1)
This formula calculates a power factor quantity known as Total Power Factor. It is called
Total PF because it is based on the ratios of the power delivered. The delivered power
quantities will include the impacts of any existing harmonic content. If the voltage or
current includes high levels of harmonic distortion the power values will be affected. By
calculating power factor from the power values, the power factor will include the impact of
harmonic distortion. In many cases this is the preferred method of calculation because the
entire impact of the actual voltage and current are included.
A second type of power factor is Displacement Power Factor. Displacement PF is based on
the angular relationship between the voltage and current. Displacement power factor
does not consider the magnitudes of voltage, current or power. It is solely based on the
phase angle differences. As a result, it does not include the impact of harmonic distortion.
Displacement power factor is calculated using the following equation:
Displacement PF = cosθ
(EQ 2.2)
where θ is the angle between the voltage and the current (see FIGURE 2–9: Voltage and
Complex Current on page 2–12).
In applications where the voltage and current are not distorted, the Total Power Factor will
equal the Displacement Power Factor. But if harmonic distortion is present, the two power
factors will not be equal.
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2.5 Harmonic Distortion
2.5.1 Harmonics of a Non-Sinusoidal Waveform
Harmonic distortion is primarily the result of high concentrations of non-linear loads.
Devices such as computer power supplies, variable speed drives and fluorescent light
ballasts make current demands that do not match the sinusoidal waveform of AC
electricity. As a result, the current waveform feeding these loads is periodic but not
sinusoidal. The following figure shows a normal, sinusoidal current waveform with a period
of a. This example has no distortion.
1000
500
t
0
–500
a
2a
–1000
FIGURE 2–10: Non-Distorted Current Waveform
The figure below shows a current waveform with a slight amount of harmonic distortion.
The waveform is still periodic and is fluctuating at the normal 60 Hz frequency (a = 1/60
second). However, the waveform is not the smooth sinusoidal form seen above.
1500
1000
500
t
0
–500
a
2a
–1000
–1500
FIGURE 2–11: Distorted Current Waveform
The distortion above can be modeled as the sum of several sinusoidal waveforms of
frequencies that are multiples of the fundamental 60 Hz frequency. This modeling is
performed by mathematically reducing the distorted waveform into a collection of higher
2–14
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frequency waveforms. These higher frequency waveforms are referred to as harmonics.
The following figure shows the content of the harmonic frequencies that comprise one
cycle of the distorted portion of the above waveform.
250
200
150
100
50
t
0
a
-50
-100
-150
-200
-250
FIGURE 2–12: Harmonics for Distorted Current Waveform
The waveforms above provide an indication of the impact of combining multiple harmonic
frequencies together. The broken lines represent the 3rd, 5th, and 7th current harmonics.
The solid line represents the sum of the three harmonics.
When harmonics are present, it is important to remember that they are operating at
higher frequencies. As such, they do not always respond in the same manner as 60 Hz
values.
2.5.2 Inductive and Capacitive Impedance
Inductive and capacitive impedance are present in all power systems. We are accustomed
to thinking about these impedances as they perform at 60 Hz. However, these impedances
are subject to frequency variation.
XL = jωL and XC = 1 ⁄ jωC
(EQ 2.3)
At 60 Hz, ω = 377; but at 300 Hz (5th harmonic) ω = 1885. As frequency changes, the
impedance changes and system impedance characteristics that are normal at 60 Hz may
be entirely different in the presence of higher order harmonic waves.
Traditionally, the most common harmonics have been the low order odd frequencies, such
as the 3rd, 5th, 7th, and 9th. However newer, new-linear loads are introducing significant
quantities of higher order harmonics.
2.5.3 Voltage and Current Monitoring
Since much voltage monitoring and almost all current monitoring is performed using
instrument transformers, the higher order harmonics are often not visible. Instrument
transformers are designed to pass 60 Hz quantities with high accuracy. These devices,
when designed for accuracy at low frequency, do not pass high frequencies with high
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accuracy; at frequencies above about 1200 Hz they pass almost no information. So when
instrument transformers are used, they effectively filter out higher frequency harmonic
distortion making it impossible to see.
However, when monitors can be connected directly to the measured circuit (such as direct
connection to 480 V bus) the user may often see higher order harmonic distortion. An
important rule in any harmonics study is to evaluate the type of equipment and
connections before drawing a conclusion. Not being able to see harmonic distortion is not
the same as not having harmonic distortion.
2.5.4 Waveform Capture
It is common in advanced meters to perform a function commonly referred to as
waveform capture. Waveform capture is the ability of a meter to capture a present picture
of the voltage or current waveform for viewing and harmonic analysis. Typically a
waveform capture will be one or two cycles in duration and can be viewed as the actual
waveform, as a spectral view of the harmonic content, or a tabular view showing the
magnitude and phase shift of each harmonic value. Data collected with waveform capture
is typically not saved to memory. Waveform capture is a real-time data collection event.
Waveform capture should not be confused with waveform recording that is used to record
multiple cycles of all voltage and current waveforms in response to a transient condition.
2–16
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2.6 Power Quality
2.6.1 Description
Power quality can mean several different things. The terms power quality and power
quality problem have been applied to all types of conditions. A simple definition of power
quality problem is any voltage, current or frequency deviation that results in misoperation
or failure of customer equipment or systems. The causes of power quality problems vary
widely and may originate in the customer equipment, in an adjacent customer facility or
with the utility.
In his book Power Quality Primer, Barry Kennedy provided information on different types of
power quality problems. Some of that information is summarized in the following table.
Table 2–3: Typical Power Quality Problems
Cause
Disturbance Type
Source(s)
Lightning;
Impulse
transient
Transient voltage disturbance,
sub-cycle duration
Electrostatic discharge;
Load switching;
Capacitor switching
Oscillatory
transient with
decay
Line/cable switching;
Capacitor switching;
Load switching
Transient voltage, sub-cycle
duration
RMS voltage, multiple cycle
duration
Sag/swell
Remote system faults
System protection;
Circuit breakers;
Fuses;
RMS voltage, multiple second or
longer duration
Interruptions
Maintenance
RMS voltage, steady state,
multiple second or longer
duration
Motor starting;
Load variations;
Load dropping
Undervoltage/
Overvoltage
Intermittent loads;
Motor starting;
Arc furnaces
RMS voltage, steady state,
repetitive condition
Voltage flicker
Harmonic
distortion
Steady-state current or voltage,
long term duration
Non-linear loads;
System resonance
It is often assumed that power quality problems originate with the utility. While it is true
that may power quality problems can originate with the utility system, many problems
originate with customer equipment. Customer-caused problems may manifest themselves
inside the customer location or they may be transported by the utility system to another
adjacent customer. Often, equipment that is sensitive to power quality problems may in
fact also be the cause of the problem.
If a power quality problem is suspected, it is generally wise to consult a power quality
professional for assistance in defining the cause and possible solutions to the problem.
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GE Consumer & Industrial
Multilin
EPM 6000 Multi-function Power
Metering System
Chapter 3: Installation
Installation
3.1 Mechanical Installation
3.1.1 Dimensions
The EPM 6000 meter can be installed using a standard ANSI C39.1 (4" round) or an IEC
92 mm DIN (square) form. In new installations, simply use existing DIN or ANSI punches. For
existing panels, pull out old analog meters and replace with the EPM 6000. The various
models use the same installation. See Wiring Diagrams on page 3–9 for various Wye and
Delta wiring diagrams.
FIGURE 3–1: Bezel, Side, and Back Dimensions
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FIGURE 3–2: ANSI and DIN Mounting Panel Cutouts
3.1.2 ANSI Installation Steps
Mount the meter in a dry location free from dirt and corrosive substances. The meter is
designed to withstand harsh environmental conditions (see the Environmental
specifications in Chapter 2 for additional details).
Use the following steps to install the meter:
Z Insert the four threaded rods by hand into the back of the meter.
Twist until secure.
Z Slide the ANSI 12 mounting gasket onto the back of the meter with
the rods in place.
Z Slide the meter with the mounting gasket into the panel.
Z Secure from the back of the panel with a lock washer and nut on
each threaded rod.
Use a small wrench to tighten – do not overtighten.
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NEMA12 mounting
gasket
threaded rods
lock washer
and nut
FIGURE 3–3: ANSI Mounting Procedure
3.1.3 DIN Installation Steps
Mount the meter in a dry location free from dirt and corrosive substances. The meter is
designed to withstand harsh environmental conditions (see the Environmental
specifications in Chapter 2 for additional details).
Use the following steps to install the meter:
Z Slide the meter with NEMA 12 mounting gasket into panel.
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Z From back of the panel, slide 2 DIN mounting brackets into the
grooves on the top and bottom of the meter housing, then snap
into place.
Z Secure meter to panel with a lock washer and #8 screw through
each of the two mounting brackets.
Tighten with a #2 Phillips screwdriver – do not overtighten.
DIN mounting
bracket
top-mounting
bracket groove
bottom mounting
bracket groove
#8 screw
EPM 6000 meter
with NEMA 12
mounting gasket
FIGURE 3–4: DIN Mounting Procedure
3–4
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3.2 Electrical Installation
3.2.1 Installation Considerations
Installation of the EPM 6000 Power Metering System must be performed by only qualified
personnel who follow standard safety precautions during all procedures. Those personnel
should have appropriate training and experience with high voltage devices. Appropriate
safety gloves, safety glasses and protective clothing is recommended.
During normal operation of the EPM 6000, dangerous voltages flow through many parts of
the meter, including: Terminals and any connected CTs (current transformers) and PTs
(potential transformers), all input/output modules and their circuits. All primary and
secondary circuits can, at times, produce lethal voltages and currents. Avoid contact with
any current-carrying surfaces.
Do not use the meter or any I/O output device for primary protection or in an energy-
limiting capacity. The meter can only be used as secondary protection. Do not use the
meter for applications where failure of the meter may cause harm or death. Do not use the
meter for any application where there may be a risk of fire.
All meter terminals should be inaccessible after installation.
Do not apply more than the maximum voltage the meter or any attached device can
withstand. Refer to meter and/or device labels and to the Specifications for all devices
before applying voltages. Do not hi-pot/dielectric test any outputs, inputs or
communications terminals.
GE recommends the use of shorting blocks and fuses for voltage leads and power supply
to prevent hazardous voltage conditions or damage to CTs, if the meter needs to be
removed from service. CT grounding is optional.
If the equipment is used in a manner not specified by the manufacturer, the protection
provided by the equipment may be impaired.
Note
There is no required preventive maintenance or inspection necessary for safety. however,
any repair or maintenance should be performed by the factory.
DISCONNECT DEVICE: The following part is considered the equipment disconnect
device.
A switch or circuit-breaker must be included in the end-use equipment or building
installation. The switch shall be in close proximity to the equipment and within easy
reach of the operator. The switch shall be marked as the disconnecting device for the
equipment.
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3.2.2 CT Leads Terminated to Meter
The EPM 6000 is designed to have current inputs wired in one of three ways. The figure
below shows the most typical connection, where CT Leads are terminated to the meter at
the current gills. This connection uses nickel-plated brass studs (current gills) with screws
at each end. This connection allows the CT wires to be terminated using either an “O” or a
“U” lug. Tighten the screws with a #2 Phillips screwdriver.
Current gills
(nickel-plated
brass stud)
FIGURE 3–5: CT Leads Terminated to Meter
Wiring diagrams are detailed in Wiring Diagrams on page 3–9. Communications
connections are detailed in Communications Setup on page 3–19.
3.2.3 CT Leads Pass-Through (No Meter Termination)
The second method allows the CT wires to pass through the CT Inputs without terminating
at the meter. In this case, remove the current gills and place the CT wire directly through
the CT opening. The opening will accommodate up to 0.177" / 4.5 mm maximum diameter
CT wire.
3–6
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CT wire passing
through the meter
Current gills
removed
FIGURE 3–6: Pass-Through Wire Electrical Connection
3.2.4 Quick Connect Crimp CT Terminations
For quick termination or for portable applications, a quick connect crimp CT connection
can also be used.
Crimp CT
terminations
FIGURE 3–7: Quick Connect Electrical Connection
3.2.5 Voltage and Power Supply Connections
Voltage Inputs are connected to the back of the unit via a optional wire connectors. The
connectors accommodate up to AWG#12 / 2.5 mm wire.
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Power supply
inputs
RS485 outputs
(do not place voltage
on these terminals!)
Voltage
inputs
FIGURE 3–8: Voltage Connection
3.2.6 Ground Connections
The EPM 6000 ground terminals (
) should be connected directly to the installation's
protective earth ground. Use 2.5 mm wire for this connection.
GE recommends the use of fuses on each of the sense voltages and on the control power,
even though the wiring diagrams in this chapter do not show them.
•
•
Use a 0.1 A fuse on each voltage input.
Use a 3 A fuse on the power supply.
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3.3 Wiring Diagrams
3.3.1 Description
Choose the diagram that best suits your application and maintains the CT polarity.
1. Three-phase, four-wire system Wye with direct voltage, 3 element.
2. Three-phase, four-wire system Wye with direct voltage, 2.5 element.
3. Three-phase, four-wire Wye with PTs, 3 element.
4. Three-phase, four-wire Wye with PTs, 2.5 element.
5. Three-phase, three-wire Delta with direct voltage.
6. Three-phase, three-wire Delta with PTs.
7. Current-only measurement (three-phase).
8. Current-only measurement (dual-phase).
9. Current-only measurement (single-phase).
These diagrams are indicated in the sections following.
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3.3.2 Wye, 4-Wire with no PTs and 3 CTs, 3 Element
For this wiring type, select 3 EL WYE (3-element Wye) in the meter programming setup.
FIGURE 3–9: 4-Wire Wye with no PTs and 3 CTs, 3 Element
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3.3.3 Wye, 4-Wire with no PTs and 3 CTs, 2.5 Element
For this wiring type, select 2.5EL WYE (2.5-element Wye) in the meter programming setup.
FIGURE 3–10: 4-Wire Wye with no PTs and 3 CTs, 2.5 Element
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3.3.4 Wye, 4-Wire with 3 PTs and 3 CTs, 3 Element
For this wiring type, select 3 EL WYE (3-element Wye) in the meter programming setup.
FIGURE 3–11: 4-Wire Wye with 3 PTs and 3 CTs, 3 Element
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3.3.5 Wye, 4-Wire with 2 PTs and 3 CTs, 2.5 Element
For this wiring type, select 2.5EL WYE (2.5-element Wye) in the meter programming setup.
FIGURE 3–12: 4-Wire Wye with 2 PTs and 3 CTs, 2.5 Element
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3.3.6 Delta, 3-Wire with no PTs and 2 CTs
For this wiring type, select 2 Ct dEL (2 CT Delta) in the meter programming setup.
FIGURE 3–13: 3-Wire Delta with no PTs and 2 CTs
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3.3.7 Delta, 3-Wire with 2 PTs and 2 CTs
For this wiring type, select 2 Ct dEL (2 CT Delta) in the meter programming setup.
FIGURE 3–14: 3-Wire Delta with 2 PTs and 2 CTs
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3.3.8 Current-Only Measurement (Three-Phase)
For this wiring type, select 3 EL WYE (3 Element Wye) in the meter programming setup.
Note
Even if the meter is used only for current measurement, the unit requires a AN volts
reference. Please ensure that the voltage input is attached to the meter. AC control power
can be used to provide the reference signal.
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3.3.9 Current-Only Measurement (Dual-Phase)
For this wiring type, select 3 EL WYE (3 Element Wye) in the meter programming setup.
Note
Even if the meter is used only for current measurement, the unit requires a AN volts
reference. Please ensure that the voltage input is attached to the meter. AC control power
can be used to provide the reference signal.
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3.3.10 Current-Only Measurement (Single-Phase)
For this wiring type, select 3 EL WYE (3 Element Wye) in the meter programming setup.
Note
Even if the meter is used only for current measurement, the unit requires a AN volts
reference. Please ensure that the voltage input is attached to the meter. AC control power
can be used to provide the reference signal.
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3.4 Communications Setup
3.4.1 Description
The EPM 6000 Power Metering System provides two independent communication ports.
The first port, COM1, is an optical IrDA port. The second port, COM2, provides RS485
communication via the Modbus protocol.
3.4.2 IrDA COM1 Port
The COM1 IrDA port is located on the meter faceplate. The IrDA port allows the unit to be
set up and programmed using a remote laptop without the need for a communication
cable. Just point at the meter with an IrDA-equipped computer to configure it.
Use the GE Communicator software package that works with the EPM 6000 IrDA port to
configure the port and poll readings. Refer to the GE Communicator User Manual for details
on programming and accessing readings.
Wireless Communication
Direct PC Interface
Modbus
Serial RS485
Master Host
FIGURE 3–15: Simultaneous Dual Communications Paths
Settings for the COM1 IrDA port are configured using GE Communicator software. This port
communicates via the Modbus ASCII protocol only.
3.4.3 RS485 COM2 Port
The EPM 6000 COM2 port uses standard 2-wire, half-duplex RS485 communications. The
RS485 connector is located on the back face of the meter. A connection can easily be
established to a master device or to other slave devices, as indicated below.
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FIGURE 3–16: RS485 Communications Installation
The EPM 6000 COM2 port can be programmed through the faceplate or with software.
The standard RS485 port settings are:
Address: 001 to 247
Baud rate: 9.6, 19.2, 38.4, or 57.6 kbps
Protocol: Modbus RTU, Modbus ASCII, or DNP 3.0
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EPM 6000 Multi-function Power
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Chapter 4: Using the Meter
Using the Meter
4.1 Front Panel Interface
4.1.1 Description
The EPM 6000 Power Metering System can be configured and a variety of functions can be
accomplished simply by using the elements and the buttons on the meter faceplate. This
chapter will review front panel navigation. Complete navigation maps can be found in
Navigation Maps on page 6–1.
4.1.2 Faceplate Elements
The meter faceplate elements are described below.
•
•
•
•
•
•
Reading Type Designator: indicates type of reading.
IrDA Communication Port: COM1 port for wireless communications.
% of Load Bar: graphic display of current as a percentage of the load.
Parameter Designator: indicates the reading displayed.
Watt-Hour Pulse: energy pulse output to test accuracy.
Scale Selector: “kilo” or “mega” multiplier of displayed readings.
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Parameter
designator
Reading
type indicator
IRDA communications
port
Watt-hour
pulse
% of Load Bar
FIGURE 4–1: EPM 6000 Faceplate Elements
4.1.3 Faceplate Buttons
The following functions can be performed using the MENU, ENTER, DOWN and RIGHT
buttons:
•
•
•
•
•
•
•
•
•
View meter information
Enter display modes
Configure parameters (password protected)
Perform resets
Perform LED checks
Change settings
View parameter values
Scroll parameter values
View limit states
The faceplate buttons function as follows:
•
Enter button: Press and release the ENTER button to select one of four display
modes: operating mode (default), reset mode (press ENTER once, followed by
DOWN), settings mode (press ENTER twice, followed by DOWN), and configuration
mode (press ENTER three times, followed by DOWN).
•
•
•
Menu button: Press and release to navigate the configuration menu and again to
return to the main menu.
Right button: Press the RIGHT button to enter the menus for the operate, reset,
settings, and configuration mode.
Down button: Press the DOWN button to scroll through the menus for each of the
modes.
In operating mode (default), the faceplate buttons are used to view parameter values. In
reset mode, the buttons are used to restore maximum and minimum values. In settings
mode, the buttons are used to view settings parameters and change the scroll setting. In
configuration mode, the buttons are used to change meter configuration (in this case, they
can be password protected).
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MENU
button
ENTER
button
RIGHT
button
DOWN
button
FIGURE 4–2: EPM 6000 Faceplate Buttons
4.1.4 Percentage of Load Bar
The 10-segment LED bar graph at the bottom of the EPM 6000 front panel provides a
graphic representation of current. The segments illuminate according to the load shown in
the table below. When the load is greater than 120% of full-load, all segments flash “ON”
for 1.5 seconds and “OFF” for 0.5 seconds.
Table 4–1: % of Load Bar Segments
Segments
Load ≥ % Full Load
no load
none
1
1%
1 to 2
1 to 3
1 to 4
1 to 5
1 to 6
1 to 7
1 to 8
1 to 9
1 to 10
15%
30%
45%
60%
72%
84%
96%
108%
120%
>120%
all blinking
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4.1.5 Watt-Hour Accuracy Testing (Verification)
To be certified for revenue metering, power providers and utility companies have to verify
that the billing energy meter will perform to the stated accuracy. To confirm the meter's
performance and calibration, power providers use field test standards to ensure that the
unit's energy measurements are correct. Since the EPM 6000 is a traceable revenue meter,
it contains a utility grade test pulse that can be used to gate an accuracy standard. This is
an essential feature required of all billing grade meters.
FIGURE 4–3: Using the Watt-Hour Test Probe
The following table lists the watt-hour pulse constants for accuracy testing.
Table 4–2: EPM 6000 Accuracy Test Constants
Voltage Level
Below 150 V
Above 150 V
Class 10 Models
0.2505759630
1.0023038521
Class 2 Models
0.0501151926
0.2004607704
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4.2 Configuring the Meter via the Front Panel
4.2.1 Overview
The EPM 6000 front panel can be used to configure the meter. The EPM 6000 has three
modes: operating mode (default), IrDA reset mode, and configuration mode. The MENU,
ENTER, DOWN and RIGHT buttons navigate through the modes and navigate through all
the screens in each mode.
A typical setup will be demonstrated in this section; other settings are possible. Complete
navigation maps for the display modes are shown in Navigation Maps on page 6–1. The
meter can also be configured through software.
4.2.2 Start Up
Upon power-up, the meter will display a sequence of screens. The sequence includes the
following screens:
Lamp test screen where all LEDs are lighted;
Lamp test screen where all digits are lighted;
Firmware screen showing build number;
Error screen (if an error exists).
The EPM 6000 will then auto-scroll the parameter designators on the right side of the front
panel. Values are displayed for each parameter. The KILO or MEGA LED will illuminate,
showing the scale for the Wh, varh and VAh readings.
An example of a Wh reading is shown below.
FIGURE 4–4: Typical Wh Reading
The EPM 6000 will continue to scroll through the parameter designators, providing
readings until one of the buttons on the front panel is pushed, causing the meter to enter
one of the other modes.
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4.2.3 Main Menu
The following procedure describes how the navigate the main menu.
Z Push the MENU button from any of the auto-scrolling readings to
display the main menu screens.
The string for reset mode (rSt) will be blinking in the “A” Screen.
Z Press the DOWN key to scroll the menu and display the
configuration mode string (CFG) in the “A” screen.
Z Press the DOWN key again to scroll the menu and display the
operating mode string in the “A” screen.
Z Press the DOWN key again to scroll back to reset mode (rSt).
Z Press ENTER from the main menu to enter the mode displayed on
the “A” screen. See Main Menu Screens on page 6–2 for navigation
details.
FIGURE 4–5: Main Menu Screens
4.2.4 Reset Mode and Password Entry
The following procedure describes how the navigate the reset mode menu.
Z Press ENTER while the “A” screen is in reset mode (i.e., the “A”
screen displays rSt).
The rSt ALL? no message will appear. The rSt ALL? function
resets all maximum and minimum values.
Z Press ENTER to continue scrolling through the main menu.
The DOWN button does not change the screen.
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Z Press the RIGHT button to display the rSt ALL? YES message.
Resetting the maximum and minimum value requires entry of a four-digit password, if
enabled in software.
Z Press ENTER to display the password screen.
If password is enabled in the software, the screen displays the PASS message in the “A”
screen and 4 dashes in the “B” screen, with the left-most digit flashing.
Z Using the DOWN button, select 0 to 9 for the flashing digit.
Z When the desired number appears, use the RIGHT button to select
it and move to the next digit.
Z When all four password digits have been selected, press ENTER.
If the correct password has been entered, the rSt ALL donE message appears and the
screen returns to auto-scroll the parameters.
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If an incorrect password has been entered, the PASS ---- FAIL message appears and
the screen returns to the rSt ALL? YES message.
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4.3 Changing Settings in Configuration Mode
4.3.1 Description
The following procedure describes how the navigate the configuration mode menu.
Z Press the MENU Button from any of the auto-scrolling readings.
Z Press DOWN to display the configuration mode (CFG) in the “A”
screen.
w
Press ENTER to scroll through the configuration parameters,
starting at the SCrL Ct Pt screen.
Z Push the DOWN Button to scroll all the parameters: scroll, CT, PT,
connection (Cnct) and port.
The active parameter is always flashing and displayed in the “A”
screen.
4.3.2 Configuring the Scroll Feature
Use the following procedure to configure the scroll feature.
Z Press the ENTER button to display the SCrL no message.
Z Press the RIGHT button to change the display to SCrL YES as
shown below.
FIGURE 4–6: Scroll Mode Configuration
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When in scroll mode, the unit scrolls each parameter for 7 seconds on and 1 second off.
The meter can be configured through software to only display selected screens. In this
case, it will only scroll the selected displays.
Z Push ENTER to select YES or no.
Z Scroll to the CT parameters screen.
4.3.3 Programming the Configuration Mode Screens
Use the following procedure to program the screen for configuration mode.
Z Press the DOWN or RIGHT button (for example, from the Ct-n
message below) to display the password screen, if enabled in the
software.
Z Use the DOWN and RIGHT buttons to enter the correct password
(refer to Reset Mode and Password Entry on page 4–6 for steps on
password entry).
Z Once the correct password is entered, push ENTER.
The Ct-n message will reappear, the PRG faceplate LED will flash,
and the first digit of the “B” screen will also flash.
Z Use the DOWN button to change the first digit.
Z Use the RIGHT button to select and change the successive digits.
Z When the new value is entered, push ENTER twice.
This will display the Stor ALL? no screen.
Z Use the RIGHT button to scroll to change the value from no to YES.
Z When the Stor ALL? YES message is displayed, press ENTER to
change the setting.
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CHAPTER 4: USING THE METER
The Stor ALL donE message will appear and the meter will reset.
4.3.4 Configuring the CT Setting
Use the following procedure to program the CT setting.
Z Push the DOWN Button to scroll through the configuration mode
parameters.
Press ENTER when Ct is the active parameter (i.e. it is in the “A” screen and flashing).
This will display the and the Ct-n (CT numerator) screen.
Z Press ENTER again to change to display the Ct-d (CT denominator)
screen.
The Ct-d value is preset to a 1 or 5 A at the factory and cannot be changed.
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Z Press ENTER again to select the to Ct-S (CT scaling) value.
The Ct-S value can be “1”, “10”, or “100”. Refer to Programming the Configuration Mode
Screens on page 4–10 for instructions on changing values.
Note
The value for amps is a product of the Ct-n and the Ct-S values.
Example settings for the Ct-S value are shown below:
200/5 A: set the Ct-n value for “200” and the Ct-S value for “1”
800/5 A: set the Ct-n value for “800” and the Ct-S value for “1”
2000/5 A: set the Ct-n value for “2000” and the Ct-S value for “1”.
10000/5 A: set the Ct-n value for “1000” and the Ct-S value for “10”.
Z Press ENTER to scroll through the other CFG parameters.
Pressing DOWN or RIGHT displays the password screen (see Reset
Mode and Password Entry on page 4–6 for details).
Z Press MENU to return to the main configuration menu.
Note
Ct-n and Ct-S are dictated by primary current. Ct-d is secondary current.
4.3.5 Configuring the PT Setting
Use the following procedure to program the PT setting.
Z Push the DOWN Button to scroll through the configuration mode
parameters.
Z Press ENTER when Pt is the active parameter (i.e. it is in the “A”
screen and flashing).
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This will display the and the Pt-n (PT numerator) screen.
Z Press ENTER again to change to display the Pt-d (PT denominator)
screen.
Z Press ENTER again to select the to Pt-S (PT scaling) value.
The Pt-S value can be “1”, “10”, or “100”. Refer to Programming the Configuration Mode
Screens on page 4–10 for instructions on changing values.
Example settings for the Pt-n, Pt-d, and Pt-S values are shown below:
•
•
•
14400/120 V (reads 14400 V): set Pt-n to “1440”, Pt-d to “120”, and Pt-S
to “10”
138000/69 V (reads 138000 V): set Pt-n to “1380”, Pt-d to “69”, and Pt-S
to “100”
345000/115 V (reads 347000 V): set Pt-n to “3450”, Pt-d to “115”, and
Pt-S to “100”
Z Press ENTER to scroll through the other CFG parameters.
Z Press DOWN or RIGHT to display the password screen (see Reset
Mode and Password Entry on page 4–6 for details).
Z Press MENU to return to the main configuration menu.
Note
Pt-n and Pt-S are dictated by primary voltage. Pt-d is secondary voltage.
4.3.6 Configuring the Connection Setting
Use the following procedure to program the connection (Cnct) setting.
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Z Push the DOWN Button to scroll through the configuration mode
parameters.
Z Press ENTER when Cnct is the active parameter (i.e. it is in the “A”
screen and flashing).
This will display the Cnct (connection) screen. The possible connection configurations are
3-element Wye (3 EL WYE), 2.5-element Wye (2.5EL WYE), and 2 CT Delta (2 Ct deL), as
shown below.
3-Element Wye
2.5-Element Wye
2 CT Delta
Z Press ENTER to scroll through the other CFG parameters.
Z Press DOWN or RIGHT to display the password screen (see Reset
Mode and Password Entry on page 4–6 for details).
Z Press MENU to return to the main configuration menu.
4.3.7 Configuring the Communication Port Setting
Use the following procedure to program the communication port (POrt) settings.
Z Push the DOWN Button to scroll through the configuration mode
parameters.
Z Press ENTER when POrt is the active parameter (i.e. it is in the “A”
screen and flashing).
The following parameters can be configured through the POrt menu
•
•
The meter address (Adr, a 3-digit number).
The baud rate (bAUd). Select from “9600”, “19.2”, “38.4”, and “57.6” for 9600, 19200,
38400, and 57600 kbps, respectively.
•
The communications protocol (Prot).
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Z Select “rtU” for Modbus RTU, “ASCI” for Modbus ASCII, and “dnP” for
the DNP 3.0 protocol.
•
The first POrt screen is meter address (Adr). The current address appears on the
screen.
Z Select three-digit number for the address.
Refer to Programming the Configuration Mode Screens on page 4–
10 for details on changing values.
Address 005
•
The next POrt screen is the baud rate (bAUd). The current baud rate is displayed
on the “B” screen. Refer to Programming the Configuration Mode Screens on page
4–10 for details on changing values. The possible baud rate screens are shown
below.
•
The final POrt screen is the communications protocol (Prot).
The current protocol is displayed on the “B” screen.
Refer to Programming the Configuration Mode Screens on page 4–10 for details on
changing values. The three protocol selections are shown below.
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Z Press ENTER to scroll through the other CFG parameters.
Z Press DOWN or RIGHT to display the password screen (see Reset
Mode and Password Entry on page 4–6 for details).
Z Press MENU to return to the main configuration menu.
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4.4 Operating Mode
4.4.1 Description
Operating mode is the EPM 6000 meter’s default mode. If scrolling is enabled, the meter
automatically scrolls through these parameter screens after startup. The screen changes
every 7 seconds. Scrolling is suspended for 3 minutes after any button is pressed.
Push the DOWN button to scroll all the parameters in operating mode. The active
parameter has the indicator light next to it on the right face of the meter. Push the RIGHT
button to view additional displays for that parameter. A table of the possible displays in the
operating mode is below. Refer to Operating Mode Screens on page 6–3 for a detailed
navigation map of the operating mode.
Table 4–3: Operating Mode Parameter Readings
Parameter
designator
Possible display readings
VOLTS_LN_
MAX
VOLTS_LN_
MIN
VOLTS_LN_
THD
VOLTS L-N
VOLTS_LN
VOLTS_LL_
MAX
VOLTS_LL_
MIN
VOLTS L-L
AMPS
VOLTS_LL
AMPS_MAX
W_VAR_PF
AMPS_MIN
AMPS_THD
W_VAR_PF
_MAX_POS
W_VAR_PF
_MIN_POS
W_VAR_PF
_MAX_NEG
W/VAR/PF
VA_FREQ_
MAX
VA/Hz
VA_FREQ
VA_FREQ_ MIN
Wh
KWH_REC
KVARH_ POS
KVAH
KWH_DEL
KWH_NET
VARh
VAh
KVARH_ NEG
KVARH_ NET
Note
Readings or groups of readings are skipped if not applicable to the meter type or hookup,
or if explicitly disabled in the programmable settings.
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EPM 6000 Multi-function Power
Metering System
Chapter 5: Communications
Communications
5.1 Modbus Communications
5.1.1 Memory Map Description
The Modbus memory map is divided into four primary sections:
1. Fixed data registers: addresses 0001 to 0021.
2. Meter data registers: addresses 1000 to 5003.
The meter data registers read as “0” until the first readings are available or if
the meter is not in operating mode. Writes to these registers will be accepted
but will have no effect on the register.
3. Command registers: addresses 20000 to 26011.
The command registers always read as “0”. The may be written only when the
meter is in a suitable mode. The registers return an illegal data address
exception if a write is attempted in an incorrect mode.
4. Programmable settings registers: addresses 30000 to 30026.
All registers explicitly listed in the table read as “0”. Writes to these registers will be
accepted but won’t actually the register, since it doesn’t exist.
5.1.2 Memory Map
The Modbus memory map is shown below. Additional notes indicated in the memory map
(“See Note ...”) are located at the end of the table, as well as a description of the format
codes.
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CHAPTER 5: COMMUNICATIONS
HEX
ADDRESS
UNITS OR
RESOLUTION
DESCRIPTION1 FORMAT
RANGE6
COMMENTS
# REG
FIXED DATA SECTION
Identification Block
read-only
8
8
1
0000
-
0007 Meter Name
ASCII
ASCII
16 char
16 char
none
0008
-
000F Meter Serial Number
none
t = transducer model (1=yes, 0=no),
vvv = V-switch(1 to 4)
0010
-
0010 Meter Type
UINT16
bit-mapped
-------t -----vvv
2
1
1
0011
0013
-
-
0012 Firmware Version
0013 Map Version
ASCII
4 char
none
none
UINT16
0 to 65535
0014
-
0014 Meter Configuration
UINT16
UINT16
bit-mapped
0-65535
-------- --ffffff
none
ffffff = calibration frequency (50 or 60)
1
17
8
0015
0016
0027
-
-
-
0015 ASIC Version
0026 Reserved
002E GE Part Number
ASCII
16 char
none
47
Block Size:
read-only
2
METER DATA SECTION
Primary Readings Block, 6 cycles (IEEE Floating Point)
2
2
2
6
0383
0385
0387
-
-
-
0384 Watts, 3-Ph total
0386 VARs, 3-Ph total
0388 VAs, 3-Ph total
FLOAT
FLOAT
FLOAT
-9999 M to +9999 M
-9999 M to +9999 M
-9999 M to +9999 M
watts
VARs
VAs
Block Size:
read-only
Primary Readings Block, 60 cycles (IEEE Floating Point)
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
30
03E7
03E9
03EB
03ED
03EF
03F1
03F3
03F5
03F7
03F9
03FB
03FD
03FF
0401
0403
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
03E8 Volts A-N
03EA Volts B-N
03EC Volts C-N
03EE Volts A-B
03F0 Volts B-C
03F2 Volts C-A
03F4 Amps A
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
0 to 9999 M
volts
volts
volts
volts
volts
volts
amps
amps
amps
watts
VARs
VAs
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
03F6 Amps B
0 to 9999 M
03F8 Amps C
0 to 9999 M
03FA Watts, 3-Ph total
03FC VARs, 3-Ph total
03FE VAs, 3-Ph total
-9999 M to +9999 M
-9999 M to +9999 M
-9999 M to +9999 M
-1.00 to +1.00
0 to 65.00
0400 Power Factor, 3-Ph total FLOAT
none
Hz
0402 Frequency
FLOAT
FLOAT
0404 Neutral Current
0 to 9999 M
amps
Block Size:
read-only
Primary Energy Block
2
2
0 to 99999999 or
-99999999
0 to
0 to
* Wh received & delivered always
have opposite signs
044B
-
044C W-hours, Received
SINT32
SINT32
Wh per energy format
0 to 99999999 or
-99999999
* Wh received is positive for "view as
load", delivered is positive for "view as
generator"
044D
-
044E W-hours, Delivered
Wh per energy format
Wh per energy format
2
2
2
044F
0451
-
-
0450 W-hours, Net
0452 W-hours, Total
SINT32
SINT32
-99999999 to 99999999
0 to 99999999
Wh per energy format * 5 to 8 digits
* decimal point implied, per energy
format
0453
-
0454 VAR-hours, Positive
SINT32
0 to 99999999
VARh per energy format
* resolution of digit before decimal
point = units, kilo, or mega, per energy
format
2
2
0455
0457
-
-
0456 VAR-hours, Negative
0458 VAR-hours, Net
SINT32
SINT32
0 to -99999999
VARh per energy format
VARh per energy format
-99999999 to 99999999
5–2
EPM 6000 MULTI-FUNCTION POWER METERING SYSTEM – USER GUIDE
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CHAPTER 5: COMMUNICATIONS
HEX
ADDRESS
UNITS OR
RESOLUTION
DESCRIPTION1 FORMAT
RANGE6
COMMENTS
# REG
2
2
0459
045B
-
-
045A VAR-hours, Total
045C VA-hours, Total
SINT32
SINT32
0 to 99999999
0 to 99999999
VARh per energy format
VAh per energy format * see note 10
Block Size:
18
read-only
Primary Demand Block (IEEE Floating Point)
2
2
2
2
07CF
07D1
07D3
-
07D0 Amps A, Average
07D2 Amps B, Average
07D4 Amps C, Average
FLOAT
FLOAT
FLOAT
0 to 9999 M
0 to 9999 M
0 to 9999 M
amps
amps
amps
-
-
-
Positive Watts, 3-Ph,
07D5
07D7
07D9
07DB
07D6
FLOAT
FLOAT
FLOAT
-9999 M to +9999 M
-9999 M to +9999 M
-9999 M to +9999 M
-9999 M to +9999 M
watts
VARs
watts
VARs
Average
Positive VARs, 3-Ph,
2
2
2
-
-
-
07D8
Average
Negative Watts, 3-Ph,
07DA
Average
Negative VARs, 3-Ph,
07DC
FLOAT
FLOAT
Average
2
2
2
07DD
07DF
-
-
07DE VAs, 3-Ph, Average
-9999 M to +9999 M
-1.00 to +1.00
VAs
07E0 Positive PF, 3-Ph, Average FLOAT
Negative PF, 3-PF,
none
07E1
-
07E2
FLOAT
-1.00 to +1.00
none
Average
20
Block Size:
read-only
Primary Minimum Block (IEEE Floating Point)
2
2
2
2
2
2
2
0BB7
0BB9
0BBB
0BBD
0BBF
0BC1
-
0BB8 Volts A-N, Minimum
0BBA Volts B-N, Minimum
0BBC Volts C-N, Minimum
0BBE Volts A-B, Minimum
0BC0 Volts B-C, Minimum
0BC2 Volts C-A, Minimum
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
volts
volts
volts
volts
volts
volts
-
-
-
-
-
Amps A, Minimum Avg
0BC3
0BC5
0BC7
0BC9
0BCB
0BCD
0BCF
0BD1
-
-
-
-
-
-
-
-
0BC4
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
0 to 9999 M
amps
amps
amps
watts
VARs
watts
VARs
VAs
Demand
Amps B, Minimum Avg
2
2
2
2
2
2
2
2
0BC6
0 to 9999 M
Demand
Amps C, Minimum Avg
0BC8
0 to 9999 M
Demand
Positive Watts, 3-Ph,
0BCA
0 to +9999 M
0 to +9999 M
0 to +9999 M
0 to +9999 M
-9999 M to +9999 M
Minimum Avg Demand
Positive VARs, 3-Ph,
0BCC
Minimum Avg Demand
Negative Watts, 3-Ph,
0BCE
Minimum Avg Demand
Negative VARs, 3-Ph,
0BD0
Minimum Avg Demand
VAs, 3-Ph, Minimum Avg
0BD2
Demand
Positive Power Factor, 3-
0BD4 Ph, Minimum Avg
Demand
Negative Power Factor, 3-
0BD6 Ph, Minimum Avg
Demand
0BD3
-
FLOAT
-1.00 to +1.00
none
none
2
0BD5
0BD7
-
-
FLOAT
FLOAT
-1.00 to +1.00
0 to 65.00
2
0BD8 Frequency, Minimum
Hz
34
Block Size:
read-only
Primary Maximum Block (IEEE Floating Point)
2
2
2
2
2
2
2
0C1B
0C1D
0C1F
0C21
0C23
0C25
-
0C1C Volts A-N, Maximum
0C1E Volts B-N, Maximum
0C20 Volts C-N, Maximum
0C22 Volts A-B, Maximum
0C24 Volts B-C, Maximum
0C26 Volts C-A, Maximum
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
FLOAT
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to 9999 M
volts
volts
volts
volts
volts
volts
-
-
-
-
-
Amps A, Maximum Avg
0C27
0C29
0C2B
0C2D
-
-
-
-
0C28
FLOAT
FLOAT
FLOAT
FLOAT
0 to 9999 M
0 to 9999 M
0 to 9999 M
0 to +9999 M
amps
amps
amps
watts
Demand
Amps B, Maximum Avg
2
2
2
0C2A
Demand
Amps C, Maximum Avg
0C2C
Demand
Positive Watts, 3-Ph,
0C2E
Maximum Avg Demand
EPM 6000 MULTI-FUNCTION POWER METERING SYSTEM – USER GUIDE
5–3
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CHAPTER 5: COMMUNICATIONS
HEX
ADDRESS
UNITS OR
RESOLUTION
DESCRIPTION1 FORMAT
RANGE6
COMMENTS
# REG
Positive VARs, 3-Ph,
FLOAT
2
2
2
2
2
0C2F
0C31
0C33
0C35
-
-
-
-
0C30
0C32
0C34
0C36
0 to +9999 M
VARs
Maximum Avg Demand
Negative Watts, 3-Ph,
FLOAT
0 to +9999 M
watts
VARs
VAs
Maximum Avg Demand
Negative VARs, 3-Ph,
FLOAT
0 to +9999 M
Maximum Avg Demand
VAs, 3-Ph, Maximum Avg
FLOAT
-9999 M to +9999 M
Demand
Positive Power Factor, 3-
0C37
-
0C38 Ph, Maximum Avg
FLOAT
-1.00 to +1.00
none
Demand
Negative Power Factor, 3-
2
0C39
0C3B
-
-
0C3A Ph, Maximum Avg
Demand
FLOAT
FLOAT
-1.00 to +1.00
0 to 65.00
none
Hz
2
0C3C Frequency, Maximum
34
Block Size:
read-only
7, 13
THD Block
1
1
1
1
1
1
1
0F9F
0FA0
0FA1
0FA2
0FA3
0FA4
-
0F9F Volts A-N, %THD
0FA0 Volts B-N, %THD
0FA1 Volts C-N, %THD
0FA2 Amps A, %THD
0FA3 Amps B, %THD
0FA4 Amps C, %THD
UINT16
UINT16
UINT16
UINT16
UINT16
UINT16
0 to 9999, or 65535
0 to 9999, or 65535
0 to 9999, or 65535
0 to 9999, or 65535
0 to 9999, or 65535
0 to 9999, or 65535
0.1%
0.1%
0.1%
0.1%
0.1%
0.1%
-
-
-
-
-
Phase A Current 0th
0FA5
0FA6
0FA7
0FA8
0FA9
0FAA
0FAB
0FAC
0FAD
0FAE
0FAF
0FB0
-
-
-
-
-
-
-
-
-
-
-
-
0FA5
UINT16
UINT16
UINT16
UINT16
UINT16
UINT16
UINT16
UINT16
UINT16
UINT16
UINT16
UINT16
0 to 65535
0 to 65535
0 to 65535
0 to 65535
0 to 65535
0 to 65535
0 to 65535
0 to 65535
0 to 65535
0 to 65535
0 to 65535
0 to 65535
none
none
none
none
none
none
none
none
none
none
none
none
harmonic magnitude
Phase A Current 1st
1
1
1
1
1
1
1
1
1
1
1
0FA6
harmonic magnitude
Phase A Current 2nd
0FA7
harmonic magnitude
Phase A Current 3rd
0FA8
harmonic magnitude
Phase A Current 4th
0FA9
harmonic magnitude
Phase A Current 5th
0FAA
harmonic magnitude
Phase A Current 6th
0FAB
harmonic magnitude
Phase A Current 7th
0FAC
harmonic magnitude
Phase A Voltage 0th
0FAD
harmonic magnitude
Phase A Voltage 1st
0FAE
harmonic magnitude
Phase A Voltage 2nd
0FAF
harmonic magnitude
Phase A Voltage 3rd
0FB0
harmonic magnitude
Phase B Current
8
4
8
0FB1
0FB9
0FBD
0FC5
-
-
-
-
0FB8
same as Phase A Current 0th to 7th harmonic magnitudes
same as Phase A Voltage 0th to 3rd harmonic magnitudes
same as Phase A Current 0th to 7th harmonic magnitudes
same as Phase A Voltage 0th to 3rd harmonic magnitudes
Phase B Voltage
0FBC
Phase C Current
0FC4
Phase C Voltage
0FC8
4
42
Block Size:
read-only
14
Phase Angle Block
1
1
1
1
1
1
6
1003
1004
1005
1006
1007
1008
-
1003 Phase A Current
1004 Phase B Current
1005 Phase C Current
1006 Angle, Volts A-B
1007 Angle, Volts B-C
1008 Angle, Volts C-A
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
-1800 to +1800
-1800 to +1800
-1800 to +1800
-1800 to +1800
-1800 to +1800
-1800 to +1800
0.1 degree
0.1 degree
0.1 degree
0.1 degree
0.1 degree
0.1 degree
-
-
-
-
-
Block Size:
5–4
EPM 6000 MULTI-FUNCTION POWER METERING SYSTEM – USER GUIDE
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CHAPTER 5: COMMUNICATIONS
HEX
ADDRESS
UNITS OR
RESOLUTION
DESCRIPTION1 FORMAT
RANGE6
COMMENTS
# REG
read-only
Status Block
1
exnpch = EEPROM block OK flags
(e=energy, x=max, n=min,
p=programmable settings,
c=calibration, h=header),
1387
-
1387 Meter Status
UINT16
bit-mapped
--exnpch ssssssss
ssssssss = state (1=Run, 2=Limp,
10=Prog Set Update via buttons,
11=Prog Set Update via IrDA, 12=Prog
Set Update via COM2)
1
high byte is setpt 1, 0=in, 1=out
low byte is setpt 2, 0=in, 1=out
7
1388
1389
-
1388
UINT16
UINT32
bit-mapped
87654321 87654321
4 msec
Limits Status
2
4
-
138A Time Since Reset
0 to 4294967294
wraps around after max count
Block Size:
4
COMMANDS SECTION
9
write-only
Block Size:
Resets Block
5
1
1
4E1F
-
4E1F Reset Max/Min Blocks
UINT16
UINT16
password
Reset Energy
Accumulators
5
4E20
-
4E20
password
2
read/conditional write
Meter Programming Block
Initiate Programmable
1
1
5
55EF
-
55EF
UINT16
UINT16
meter enters PS update mode
password
Settings Update
Terminate Programmable
Settings Update
meter leaves PS update mode via
reset
55F0
-
55F0
any value
3
1
1
1
Calculate Programmable
Settings Checksum
meter calculates checksum on RAM
copy of PS block
55F1
55F2
55F3
-
-
-
55F1
55F2
55F3
UINT16
UINT16
UINT16
3
Programmable Settings
read/write checksum register; PS
3
8
Checksum
block saved in EEPROM on write
3
0000 to 9999
write-only register; always reads zero
Write New Password
Initiate Meter Firmware
Reprogramming
1
6
5
59D7
-
59D7
UINT16
password
Block Size:
read/write
Other Commands Block
1
1
causes a watchdog reset, always
reads 0
5
61A7
-
61A7 Force Meter Restart
UINT16
password
Block Size:
read/write
Encryption Block
12
12
Perform a Secure
Operation
encrypted command to read
658F
-
659A
UINT16
password or change meter type
Block Size:
PROGRAMMABLE SETTINGS SECTION
Basic Setups Block
write only in PS update mode
1
high byte is denominator (1 or 5, read-
only),
low byte is multiplier (1, 10, or 100)
CT multiplier &
dddddddd
mmmmmmmm
752F
-
752F
UINT16
bit-mapped
denominator
1
1
7530
7531
-
7530 CT numerator
7531 PT numerator
UINT16
UINT16
1 to 9999
1 to 9999
none
none
-
EPM 6000 MULTI-FUNCTION POWER METERING SYSTEM – USER GUIDE
5–5
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CHAPTER 5: COMMUNICATIONS
HEX
ADDRESS
UNITS OR
RESOLUTION
DESCRIPTION1 FORMAT
RANGE6
COMMENTS
# REG
1
1
7532
-
7532 PT denominator
UINT16
1 to 9999
none
MMMMmmmmmmmm is PT multiplier
(1, 10, 100, 1000),
mmmmmmmm
MMMMhhhh
7533
7534
-
7533 PT multiplier & hookup
UINT16
UINT16
bit-mapped
bit-mapped
hhhh is hookup enumeration (0 = 3
element wye[9S], 1 = delta 2 CTs[5S], 3
= 2.5 element wye[6S])
1
1
iiiiii = interval (5,15,30,60)
b = 0-block or 1-rolling
sss = # subintervals (1,2,3,4)
-
-
7534 Averaging Method
--iiiiii b----sss
pppp = power scale (0-unit, 3-kilo, 6-
mega, 8-auto)
nn = number of energy digits (5-8 -->
0-3)
7535
7535 Power & Energy Format UINT16
bit-mapped
bit-mapped
pppp--nn -eee-ddd
00000000 eeeeeeee
eee = energy scale (0-unit, 3-kilo, 6-
mega)
ddd = energy digits after decimal
point (0-6)
See note 10.
1
eeeeeeee = op mode screen rows
on(1) or off(0), rows top to bottom are
bits low order to high order
Operating Mode Screen
Enables
7536
7537
-
-
7536
UINT16
7
1
753D Reserved
g = enable alternate full scale
bargraph current (1=on, 0=off)
nn = number of phases for voltage &
current screens (3=ABC, 2=AB, 1=A,
0=ABC)
s = scroll (1=on, 0=off)
753E
-
753E User Settings Flags
UINT16
bit-mapped
---g--nn srp--wf-
r = password for reset in use (1=on,
0=off)
p = password for configuration in use
(1=on, 0=off)
w = pwr dir (0-view as load, 1-view as
generator)
f = flip power factor sign (1=yes, 0=no)
1
If non-zero and user settings bit g is
set, this value replaces CT numerator
in the full scale current calculation.
Full Scale Current (for load
% bargraph)
753F
-
753F
UINT16
0 to 9999
none
8
1
7540
7548
-
-
7547 Meter Designation
7548 COM1 setup
ASCII
16 char
none
dddd = reply delay (* 50 msec)
ppp = protocol (1-Modbus RTU, 2-
Modbus ASCII, 3-DNP)
UINT16
bit-mapped
----dddd -0100110
1
bbb = baud rate (1-9600, 2-19200, 4-
38400, 6-57600)
7549
-
7549 COM2 setup
UINT16
bit-mapped
----dddd -ppp-bbb
none
1
1
754A
754B
-
-
754A COM2 address
UINT16
UINT16
1 to 247
use Modbus address as the identifier
(see notes 7, 11, 12)
754B Limit #1 Identifier
0 to 65535
1
1
Limit #1 Out High
Setpoint for the "above" limit (LM1),
see notes 11-12.
754C
754D
754E
754F
-
-
-
-
754C
SINT16
-200.0 to +200.0
-200.0 to +200.0
-200.0 to +200.0
-200.0 to +200.0
0.1% of full scale
0.1% of full scale
0.1% of full scale
0.1% of full scale
Setpoint
Threshold at which "above" limit
clears; normally less than or equal to
the "above" setpoint; see notes 11-12.
754D Limit #1 In High ThresholdSINT16
754E Limit #1 Out Low SetpointSINT16
754F Limit #1 In Low Threshold SINT16
1
1
Setpoint for the "below" limit (LM2),
see notes 11-12.
Threshold at which "below" limit
clears; normally greater than or equal
to the "below" setpoint; see notes 11-
12.
5–6
EPM 6000 MULTI-FUNCTION POWER METERING SYSTEM – USER GUIDE
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CHAPTER 5: COMMUNICATIONS
HEX
ADDRESS
UNITS OR
RESOLUTION
DESCRIPTION1 FORMAT
RANGE6
COMMENTS
# REG
5
5
7550
-
-
-
-
-
-
-
7554 Limit #2
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
7555
755A
755F
7564
7569
756E
7559 Limit #3
755E Limit #4
7563 Limit #5
7568 Limit #6
756D Limit #7
7572 Limit #8
5
5
same as Limit #1
same as Limit #1
same as Limit #1
5
5
5
68
Block Size:
SECONDARY READINGS SECTION
Secondary Block
read-only except as noted
1
1
1
1
1
1
1
1
1
1
1
9C40
9C41
9C42
9C43
9C44
9C45
9C46
9C47
9C48
9C49
-
-
-
-
-
-
-
-
-
-
9C40 System Sanity Indicator UINT16
0 or 1
none
volts
volts
volts
amps
amps
amps
watts
VARs
VAs
0 indicates proper meter operation
2047= 0, 4095= +150
9C41 Volts A-N
9C42 Volts B-N
9C43 Volts C-N
9C44 Amps A
UINT16
UINT16
UINT16
UINT16
UINT16
UINT16
UINT16
UINT16
UINT16
2047 to 4095
2047 to 4095
2047 to 4095
0 to 4095
volts = 150 * (register - 2047) / 2047
0= -10, 2047= 0, 4095= +10
9C45 Amps B
0 to 4095
amps = 10 * (register - 2047) / 2047
9C46 Amps C
0 to 4095
9C47 Watts, 3-Ph total
9C48 VARs, 3-Ph total
9C49 VAs, 3-Ph total
0 to 4095
0= -3000, 2047= 0, 4095= +3000
watts, VARs, VAs =
0 to 4095
2047 to 4095
3000 * (register - 2047) / 2047
1047= -1, 2047= 0, 3047= +1
pf = (register - 2047) / 1000
9C4A
-
9C4A Power Factor, 3-Ph total UINT16
1047 to 3047
0 to 2730
none
1
0= 45 or less, 2047= 60, 2730= 65 or
more
freq = 45 + ((register / 4095) * 30)
9C4B
-
9C4B Frequency
UINT16
Hz
1
1
1
1
1
1
1
1
1
2
2
9C4C
9C4D
9C4E
9C4F
9C50
9C51
-
-
-
-
-
-
9C4C Volts A-B
UINT16
UINT16
UINT16
UINT16
UINT16
UINT16
2047 to 4095
2047 to 4095
2047 to 4095
1 to 9999
volts
volts
volts
none
none
none
2047= 0, 4095= +300
9C4D Volts B-C
volts = 300 * (register - 2047) / 2047
9C4E Volts C-A
9C4F CT numerator
9C50 CT multiplier
9C51 CT denominator
CT = numerator * multiplier /
denominator
1, 10, 100
1 or 5
9C52
9C53
9C54
9C55
-
-
-
-
9C52 PT numerator
9C53 PT multiplier
UINT16
UINT16
UINT16
UINT32
1 to 9999
none
none
none
PT = numerator * multiplier /
denominator
1, 10, 100
9C54 PT denominator
9C56 W-hours, Positive
1 to 9999
0 to 99999999
Wh per energy format * 5 to 8 digits
* decimal point implied, per energy
format
9C57
-
9C58 W-hours, Negative
UINT32
0 to 99999999
Wh per energy format
* resolution of digit before decimal
point = units, kilo, or mega, per energy
format
2
2
9C59
9C5B
9C5D
9C5F
9C60
-
-
-
-
-
9C5A VAR-hours, Positive
9C5C VAR-hours, Negative
9C5E VA-hours
UINT32
UINT32
UINT32
UINT16
N/A
0 to 99999999
0 to 99999999
0 to 99999999
0 to 4095
VARh per energy format
VARh per energy format
2
VAh per energy format * see note 10
1
9C5F Neutral Current
9CA2 Reserved
amps
none
see Amps A/B/C above
67
1
N/A
Reset Energy
9CA3
5
9CA3
-
UINT16
write-only register; always reads as 0
Block Size:
password
Accumulators
100
5.1.3 Modbus Memory Map Notes
The memory map notes are indicated by number below.
1. All registers not explicitly listed in the table read as 0. Writes to these registers will be
accepted but won't actually change the register (since it doesn't exist).
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2. Meter Data Section items read as 0 until first readings are available or if the meter is
not in operating mode. Writes to these registers will be accepted but won't actually
change the register.
3. Register valid only in programmable settings update mode. In other modes these
registers read as 0 and return an illegal data address exception if a write is attempted.
4. Meter command registers always read as 0. They may be written only when the meter
is in a suitable mode. The registers return an illegal data address exception if a write is
attempted in an incorrect mode.
5. If the password is incorrect, a valid response is returned but the command is not
executed. Use 5555 for the password if passwords are disabled in the programmable
settings.
6. M denotes a 1,000,000 multiplier.
7. Not applicable to Shark 100, V-Switch 1, 2, or 3
8. Writing this register causes data to be saved permanently in EEPROM. If there is an
error while saving, a slave device failure exception is returned and programmable
settings mode automatically terminates via reset.
9. Reset commands make no sense if the meter state is LIMP. An illegal function
exception will be returned.
10. Energy registers should be reset after a format change.
11. Entities to be monitored against limits are identified by Modbus address. Entities
occupying multiple Modbus registers, such as floating point values, are identified by
the lower register addrress. If any of the 8 limits is unused, set its identifier to zero. If
the indicated Modbus register is not used or is a non-sensical entity for limits, it will
behave as an unused limit.
12. There are 2 setpoints per limit, one above and one below the expected range of
values. LM1 is the "too high" limit, LM2 is "too low". The entity goes "out of limit" on
LM1 when its value is greater than the setpoint. It remains "out of limit" until the value
drops below the in threshold. LM2 works similarly, in the opposite direction. If limits in
only one direction are of interest, set the in threshold on the "wrong" side of the
setpoint. Limits are specified as % of full scale, where full scale is automatically set
appropriately for the entity being monitored:
current FS = CT numerator * CT multiplier
voltage FS = PT numerator * PT multiplier
power FS = CT numerator * CT multiplier * PT numerator * PT multiplier * 3 [ *
SQRT(3) for delta hookup]
frequency FS = 60 (or 50)
power factor FS = 1.0
percentage FS = 100.0
angle FS = 180.0
13. THD not available shows 65535 (=0xFFFF) in all THD and harmonic magnitude
registers for the channel when V-switch=4. THD may be unavailable due to low V or I
amplitude, or delta hookup (V only).
5–8
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14. All 3 voltage angles are measured for Wye and Delta hookups. For 2.5 Element, Vac is
measured and Vab & Vbc are calculated. If a voltage phase is missing, the two
voltage angles in which it participates are set to zero. A and C phase current angles
are measured for all hookups. B phase current angle is measured for Wye and is zero
for other hookups. If a voltage phase is missing, its current angle is zero.
5.1.4 Modbus Memory Map Data Formats
The date format codes indicated in the Format column of the Modbus memory map are
described below:
ASCII: ASCII characters packed 2 per register in high, low order and without any termination
characters. For example, "Shark100" would be 4 registers containing 0x5378, 0x6172, 0x6B31,
0x3030.
SINT16 / UINT16: 16-bit signed / unsigned integer.
SINT32 / UINT32: 32-bit signed / unsigned integer spanning 2 registers. The lower-addressed register
is the high order half.
FLOAT: 32-bit IEEE floating point number spanning 2 registers. The lower-addressed register is the
high order half (i.e., contains the exponent).
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5.2 DNP Point Mapping
5.2.1 DNP Point Maps
The DNP point mappings (DNP-11 to DNP-22) for the EPM 6000 Power Metering System
shows the client-server relationship in GE Multilin’s use of the DNP protocol. The notes are
listed after the table.
Table 5–1: DNP Point Mapping (Sheet 1 of 2)
Object
Var
Point
Description
Format
Range/units
Multiplier
Comments
Binary output states (Read via Class 0 only)
0
1
Reset energy counters
BYTE
0
0
N/A
10
2
Change to Modbus RTU protocol
BYTE
N/A
Control Relay Outputs
0
1
Reset energy counters
N/A
N/A
N/A
N/A
N/A
N/A
See note 1
12
1
Change to Modbus RTU protocol
See note 2
Binary Counters (Primary; read via Class 0 only)
0
1
2
3
4
Positive watt-hours
Negative watt-hours
Positive var-hours
Negative var-hours
Total VA-hours
UINT32
UINT32
UINT32
UINT32
UINT32
0 to 99999999 Wh
0 to 99999999 Wh
0 to 99999999 varh
0 to 99999999 varh
0 to 99999999 VAh
See note 3
See note 3
See note 3
See note 3
See note 3
See note 4
See note 4
See note 4
See note 4
See note 4
20
4
Analog Inputs (Secondary; read via Class 0 only)
30
5
0
Meter health
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
0 or 1
N/A
0 = OK
1
Voltage A-N
0 to 32767 V
0 to 32767 V
0 to 32767 V
0 to 32767 V
0 to 32767 V
0 to 32767 V
0 to 32767 A
0 to 32767 A
0 to 32767 A
–32768 to +32767 W
–32768 to +32767 var
0 to 32767 VA
–1000 to 1000
0 to 9999 Hz
(150/32768)
(150/32768)
(150/32768)
(300/32768)
(300/32768)
(300/32768)
(10/32768)
(10/32768)
(10/32768)
(4500/32768)
(4500/32768)
(4500/32768)
0.001
See note 5
See note 5
See note 5
See note 6
See note 6
See note 6
See note 7
See note 7
See note 7
2
Voltage B-N
3
Voltage C-N
4
Phase voltage A-B
Phase voltage B-C
Phase voltage C-A
Phase A current
5
6
7
8
Phase B current
9
Phase C current
10
11
12
13
14
Total three-phase real power
Total three-phase reactive power
Total three-phase apparent power
Total three-phase power factor
Frequency
0.01
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Table 5–1: DNP Point Mapping (Sheet 2 of 2)
Object
Var
Point
15
Description
Format
Range/units
Multiplier
Comments
Maximum average positive three-phase
real power demand
SINT16
–32768 to +32767 W
(4500/32768)
Maximum average positive three-phase
reactive power demand
16
17
18
19
SINT16
SINT16
SINT16
SINT16
–32768 to +32767 var
–32768 to +32767 W
–32768 to +32767 var
–32768 to +32767 VA
(4500/32768)
(4500/32768)
(4500/32768)
(4500/32768)
Maximum average negative three-phase
real power demand
Maximum average negative three-phase
reactive power demand
Maximum average three-phase apparent
power demand
30
5
20
21
22
23
24
25
26
27
28
29
30
31
Phase A current angle
Phase B current angle
Phase C current angle
Phase A-B voltage angle
Phase B-C voltage angle
Phase C-A voltage angle
CT numerator
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
SINT16
–1800 to 1800°
–1800 to 1800°
–1800 to 1800°
–1800 to 1800°
–1800 to 1800°
–1800 to 1800°
1 to 9999
0.1
0.1
0.1
0.1
0.1
0.1
N/A
N/A
N/A
N/A
N/A
N/A
See note 8
CT multiplier
1, 10, or 100
1 or 5
CT denominator
PT numerator
1 to 9999
See note 9
PT multiplier
1, 10, or 100
1 to 9999
PT denominator
Internal Indication
80
1
0
Device restart bit
N/A
N/A
N/A
See note 10
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5.2.2 DNP Point Map Notes
1. Responds to Function 5 (direct operate), Qualifier Code 7 or 8, Control Code 3, Count 0,
On 1 ms, Off 0 ms ONLY.
2. Responds to Function 6 (direct operate - no acknowledge), Qualifier Code 7, Control
Code 3, Count 0, On 1 ms, Off 0 ms ONLY.
3. The multiplier = 10(n–d), where n and d are derived from the energy format. n = 0, 3, or
6 per energy format scale and d = number of decimal places.
4. Example: If energy format = 7.2 K and watt-hours counter = 1234567, with n=3 (k-
scale) and d = 2 (2 digits after decimal point), then multiplier = 10(3–2) = 10, so the
energy is 1234567 × 10 Wh, or 12345.67 kWh.
5. Values greater than 150 V secondary read 32767.
6. Values greater than 300 V secondary read 32767.
7. Values greater than 10 A secondary read 32767. For the 1 A model, the multiplier is (2/
32768) and values above 2 A secondary read 32767.
8. CT ratio = (numerator × multiplier) / denominator.
9. PT ratio = (numerator × multiplier) / denominator.
10. Clear via Function 2 (write), Qualifier Code 0.
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5.3 DNP Implementation
5.3.1 Overview
The EPM 6000 meter is capable of using RS485 as the physical layer. This is accomplished
by connecting a PC to the meter with the RS485 connection on the back face.
RS485 provides multi-drop network communication capabilities. Multiple meters may be
placed on the same bus, allowing for a master device to communicate with any of the
other devices. Appropriate network configuration and termination should be evaluated for
each installation to insure optimal performance.
The EPM 6000 communicates in DNP 3.0 using the following communications settings: 8
data bits, no parity, and 1 stop bit. The EPM 6000 can be programmed to use several
standard baud rates, including: 9600, 19200, 38400, and 57600 bps.
5.3.2 Data Link Layer
The Data Link Layer as implemented on the EPM 6000 is subject to the following
considerations.
The control byte contains several bits and a function code. Communications directed to
the meter should be primary master messages (DIR = 1, PRM = 1). Responses will be
primary non-master messages (DIR = 0, PRM = 1). Acknowledgment will be secondary non-
master messages (DIR = 0, PRM = 0).
The EPM 6000 supports all of function codes for DNP 3.0:
•
Reset of Data Link (function 0): Before confirmed communication with a master
device, the data link layer must be reset. This is necessary after a meter has been
restarted, either by applying power or reprogramming the meter. The meter must
receive a RESET command before confirmed communication may take place.
Unconfirmed communication is always possible and does not require a RESET
command.
•
•
User Data (function 3): After receiving a request for USER DATA, the meter will
generate a data link CONFIRMATION, signaling the reception of that request, before
the actual request is processed. If a response is required, it will also be sent as
UNCONFIRMED USER DATA.
Unconfirmed User Data (function 4): After receiving a request for UNCONFIRMED
USER DATA, a response will be sent as UNCONFIRMED USER DATA if required.
DNP 3.0 allows for addresses from 0 to 65534 (0000h to FFFEh) for individual device
identification, with the address 65535 (FFFFh) defined as an all stations address. Addresses
are programmable from 0 to 247 (0000h to 00F7h), and recognize address 65535 (FFFFh)
as the all stations address.
5.3.3 Transport Layer
Multiple-frame messages are not allowed for the EPM 6000. Each transport header should
indicate it is both the first frame (FIR = 1) and the final frame (FIN = 1)
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5.3.4 Application Layer
The application layer contains a header (request or response header, depending on
direction) and data.
Application headers contain the application control field and the function code. For the
application control field, multiple-fragment messages are not allowed for EPM 6000. Each
application header should indicate it is both the first fragment (FIR = 1) as well as the final
fragment (FIN = 1). Application-level confirmation is not used for the EPM 6000.
The following function codes are implemented on the EPM 6000.
•
Read (function 1): Objects supporting the READ function are Binary Outputs (object 10),
Counters (object 20), Analog Inputs (object 30), and Class (object 60). These Objects
may be read either by requesting a specific variation available as listed in DNP Point
Mapping on page 5–10, or by requesting variation 0. A READ request for variation 0 of
an object will be fulfilled with the variation listed in the DNP points table.
•
•
•
Write (function 2): The Internal Indications object (object 80), supports the WRITE
function.
Direct Operate (function 5): The Control Relay Output object (object 12) supports the
DIRECT OPERATE function.
Direct Operate - No Acknowledgment (function 6): the Change to Modbus RTU
protocol (object 12, point 1) supports the DIRECT OPERATE - NO ACKNOWLEDGMENT
function.
•
Response (function 129): Application responses from the EPM 6000 use the RESPONSE
function.
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5.4 DNP Objects and Variations
5.4.1 Description
Application Data contains information about the object and variation, as well as the
qualifier and range. The following objects and variations are supported:
•
•
•
•
•
•
Binary Output Status (object 10, variation 2)
Control Relay Output Block (object 12, variation 1)
32-Bit Binary Counter Without Flag (object 20, variation 4)
16-Bit Analog Input Without Flag (object 30, variation 5)
Class 0 Data (object 60, variation 1)
Internal Indications (object 80, variation 1)
Read requests for variation 0 will be honored on the Binary Output Status, 32-Bit Binary
Counter Without Flag, 16-Bit Analog Input Without Flag, and Class 0 Data variations.
5.4.2 Binary Output Status (Object 10, Variation 2)
The Binary Output Status supports the Read function (function 1). A READ request for
Variation 0 will be responded to with Variation 2.
The Binary Output Status is used to communicate the following metered data:
•
Energy Reset State (point 0): EPM 6000 meters accumulate power generated or
consumed over time as hour readings, which measure positive VAh and positive and
negative Wh and varh. These readings may be reset using the Control Relay Output
object (object 12). This Binary Output Status point reports whether the energy readings
are in the process of being reset or if they are accumulating. Normally, readings are
being accumulated and the state of this point is read as “0”. If the readings are in the
process of being reset, the state of this point is read as “1”.
•
Change to Modbus RTU Protocol State (point 1): EPM 6000 meters are capable of
switching from the DNP protocol to the Modbus RTU protocol. This enables the user to
update the device profile of the meter. This feature does not change the protocol
setting, as reset returns the meter to DNP. A status reading of “1” equals open (or de-
energized); a reading of “0” equals closed (or energized).
5.4.3 Control Relay Output (Object 12, Variation 1)
The Control Relay Output Block supports the following functions: Direct Operate (function 5)
and Direct Operate - No Acknowledgment (function 6).
The Control Relay Output Block is used for the following purposes:
•
Energy Reset (point 0): EPM 6000 meters accumulate power generated or consumed
over time as hour readings, which measure positive VAh and positive and negative Wh
and varh. These readings may be reset using Point 0.
The Direct Operate (function 5) function will operate only with the settings of Pulsed
ON (Code = 1 of Control Code field) once (Count =01h) for ON 1 ms and OFF 0 ms.
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•
Change to Modbus RTU Protocol (point 1): EPM 6000 meters are capable of switching
from the DNP Protocol to the Modbus RTU Protocol. This enables the user to update
the device profile of the meter. This does not change the protocol setting, as a reset
returns the meter back to DNP.
The Direct Operate - No Acknowledge (function 6) function will operate only with the
settings of Pulsed ON (Code = 1 of the Control Code field) once (Count = 01h) for ON
1 ms and OFF 0 ms.
5.4.4 32-Bit Binary Counter Without Flag (Object 20, Variation 4)
The counters support the Read function (function 1). A read request for Variation 0 will be
responded to with Variation 4.
Counters are used to communicate the hour readings measured by the EPM 6000 meter.
Refer to DNP Point Mapping on page 5–10 for details. These readings may be cleared by
using the Control Relay Output Block.
5.4.5 16-Bit Analog Input Without Flag (Object 30, Variation 5)
The analog inputs support the Read function (function 1). A read request for Variation 0 will
be responded to with Variation 5.
Refer to DNP Point Mapping on page 5–10 for details on the data measured by the analog
inputs.
•
•
•
•
•
Health Check (point 0): The health check point indicates problems detected by the
EPM 6000. A value of zero (0000h) indicates the meter does not detect a problem; non-
zero values indicate a detected anomaly.
Phase-to-Neutral Voltages (points 1 to 3): These points are formatted as two's
complement fractions. They represent a fraction of a 150 V secondary input. Inputs
greater than 150 V secondary will be pinned at 150 V secondary.
Phase-to-Phase Voltages (points 4 to 6): These points are formatted as two's
complement fractions. They represent a fraction of a 300 V secondary input. Inputs
greater than 300 V secondary will be pinned at 300 V secondary.
Phase Currents (points 7 to 9): These points are formatted as two's complement
fractions. They represent a fraction of a 10 A secondary input. Inputs greater than
10 A secondary will be pinned at 10 A secondary.
Total Real and Reactive Power (points 10 and 11): These points are formatted as two's
complement fractions. They represent a fraction of 4500 W secondary in normal
operation or 3000 W secondary in open delta operation. Inputs above/below ±4500 or
±3000 W secondary will be pinned at ±4500 or ±3000 W secondary, respectively.
•
•
Total Apparent Power (point 12): This point is formatted as a two's complement
fraction. It represents a fraction of 4500 W secondary in normal operation or 3000 W
secondary in open delta operation. Inputs above/below ±4500 or ±3000 W secondary
will be pinned at ±4500 or ±3000 W secondary, respectively.
Power Factor (point 13): This point is formatted as a two's complement integer. It
represents power factors from –1.000 (0FC18h) to +1.000 (003E8h). When in open
delta operation, the total power factor (point 13) is always zero.
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•
•
Frequency (point 14): This point is formatted as a two's complement fraction. It
represents the frequency as measured on phase A voltage in units of cHz (centiHertz,
1/100 Hz). Inputs below 45.00 Hz are pinned at 0 (0000h), while inputs above 75.00 Hz
are pinned at 9999 (270Fh).
Maximum Demands of Total Power (points 15 to 19): These points are formatted as
two's complement fractions. They represent a fraction of 4500 W secondary in normal
operation or 3000 W secondary in open delta operation. Inputs above/below ±4500 or
±3000 W secondary will be pinned at ±4500 or ±3000 W secondary, respectively.
•
•
Phase Angles (points 20 to 25): These points are formatted as two's complement
integers. They represent angles from –180.00 (0F8F8h) to +180.00 (00708h).
CT and PT Ratios (points 26 to 31): These points are formatted as two's complement
integers. They can be used to convert from units in terms of the secondary of a CT or
PT into units in terms of the primary of a CT or PT. The ratio of numerator divided by
denominator is the ratio of primary to secondary. The EPM 6000 typically uses full
scales relating primary current to 5 A and primary voltage to 120 V. However, these full
scales can range from mAs to thousands of kAs, or mVs to thousands of kVs. Example
settings are as follows:
CT example settings:
200 A: Set the Ct-n value for “200” and the Ct-S value for “1”.
800 A: Set the Ct-n value for “800” and the Ct-S value for “1”.
2000 A: Set the Ct-n value for “2000” and the Ct-S value for “1”.
10000 A: Set the Ct-n value for “1000” and the Ct-S value for “10”.
PT example settings:
120 V (reads 14400 V):
Set the Pt-n value to “1440”, Pt-d to “120”, and Pt-S to “10”.
69 V (reads 138000 V):
Set the Pt-n value to “1380”, Pt-d to “69”, and Pt-S to “100”.
115 V (reads 345000 V):
Set the Pt-n value to “3450”, Pt-d to “115”, and Pt-S to “100”.
5.4.6 Class 0 Data (Object 60, Variation 1)
The Class 0 Data object supports the Read (function 1) function. A request for Class 0 Data
from an EPM 6000 returns three object headers. Specifically, it returns 16-Bit Analog Input
Without Flags (object 30, variation 5) points 0 to 31, followed by 32-Bit Counters Without
Flags (object 20, variation 4) points 0 to 4, followed by Binary Output Status (object 10,
variation 2), points 0 to 1. There is NO Object 1.
A request for Object 60, Variation 0 will be treated as a request for Class 0 Data.
5.4.7 Internal Indications (Object 80, Variation 1)
The Internal Indications object support the Write function (function 2). Internal Indications
may be indexed by Qualifier Code 0.
The Device Restart (point 0) bit is set whenever the meter has reset. The polling device may
clear this bit by writing (function 2) to Object 80, Point 0.
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GE Consumer & Industrial
Multilin
EPM 6000 Multi-function Power
Metering System
Chapter 6: Miscellaneous
Miscellaneous
6.1 Navigation Maps
6.1.1 Introduction
The EPM 6000 meter can be configured and a variety of functions performed using the
buttons on the meter faceplate. An overview of the elements and buttons on the faceplate
can be found in Chapter 4. The meter can also be programmed using software such as GE
Communicator.
The navigation maps show in detail how to move from one screen to another and from one
display mode to another using the buttons on the meter faceplate. All display modes will
automatically return to operating mode after 10 minutes of no user activity.
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CHAPTER 6: MISCELLANEOUS
6.1.2 Main Menu Screens
The main menu navigation map is shown below.
FIGURE 6–1: Main Menu Navigation
6–2
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6.1.3 Operating Mode Screens
The operating mode navigation map is shown below.
FIGURE 6–2: Operating Mode Navigation
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CHAPTER 6: MISCELLANEOUS
6.1.4 Reset Mode Screens
The reset mode navigation map is shown below.
FIGURE 6–3: Reset Mode Navigation
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6.1.5 Configuration Mode Screens
The configuration mode navigation map is shown below.
FIGURE 6–4: Reset Mode Navigation
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CHAPTER 6: MISCELLANEOUS
6.2 Revision History
6.2.1 Release Dates
Table 6–1: Release Dates
MANUAL
GE PART NO.
EPM 6000
REVISION
RELEASE DATE
GEK-106558
GEK-106558A
GEK-106558B
GEK-106558C
1601-0215-A1
1601-0215-A2
1601-0215-A3
1601-0215-A4
1.0x
1.0x
1.0x
1.0x
24 January 2004
08 April 2005
06 September 2005
14 February 2007
6.2.2 Changes to the Manual
Table 6–2: Major Updates for 1601-0215-A4
SECT
(A3)
SECT
(A4)
CHANGE
Update
DESCRIPTION
Title
Title
Manual part number to 1601-0215-A4
1.4.2
4.1.5
1.4.2
4.1.5
Update
Update
%THD Accuracy Changed
Fig 4-3 updated
PT Settings example values changed to be more
reflective of actual customer values
4.3.5
4.3.5
Update
PT Settings example values changed to align with
above values
5.4.5
6.1.1
5.4.5
6.1.1
Update
Update
Added mention of GE Communicator software.
Table 6–3: Major Updates for 1601-0215-A3
PAGE
(A2)
PAGE
(A3)
CHANGE
DESCRIPTION
Title
3-4
Title
3-4
Update
Update
Update
Manual part number to 1601-0215-A3
Updated ELECTRICAL INSTALLATION section
Updated RS485 COMMUNICATIONS INSTALLATION
diagram
3-16
3-16
6–6
EPM 6000 MULTI-FUNCTION POWER METERING SYSTEM – USER GUIDE
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CHAPTER 6: MISCELLANEOUS
Table 6–4: Major Updates for 1601-0215-A2
PAGE
(A1)
PAGE
(A2)
CHANGE
Update
DESCRIPTION
Title
Title
Manual part number to 1601-0215-A2
2-3
2-3
2-4
2-3
---
Update
Delete
Updated ORDER CODES section
Removed ACCESSORIES section
2-4
Update
Updated INPUTS/OUTPUTS specifications
Added CURRENT ONLY MEASUREMENT (THREE-
PHASE) section
---
---
---
3-13
3-14
3-15
Add
Add
Add
Added CURRENT ONLY MEASUREMENT (DUAL-PHASE)
section
Added CURRENT ONLY MEASUREMENT (SINGLE-
PHASE) section
4-9
4-9
Update
Update
Updated CONFIGURING THE CT SETTING section
Updated CONFIGURING THE PT SETTING section
4-10
4-10
---
5-7
Add
Added DNP COMMUNICATIONS section
EPM 6000 MULTI-FUNCTION POWER METERING SYSTEM – USER GUIDE
6–7
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CHAPTER 6: MISCELLANEOUS
6.3 Warranty
6.3.1 GE Multilin Warranty
General Electric Multilin (GE Multilin) 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 Multilin 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 Multilin authorized factory outlet.
GE Multilin 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 Multilin
Standard Conditions of Sale.
6–8
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Index
A
ACCURACY......................................................................................................................................................1–7, 4–4
B
BAUD RATE................................................................................................................................................4–14, 4–15
BLONDELL’S THEOREM .......................................................................................................................................2–5
C
CATALOG NUMBERS.............................................................................................................................................1–5
CHANGES TO MANUAL..............................................................................................................................6–6, 6–7
CHANGING SETTINGS..........................................................................................................................................4–9
COMMUNICATIONS
description .................................................................................................................................................. 3–19
IrDA................................................................................................................................................................. 3–19
memory map ......................................................................................................................................5–1, 5–2
Modbus............................................................................................................................................................5–1
RS485............................................................................................................................................................. 3–19
settings ......................................................................................................................................................... 4–14
specifications................................................................................................................................................1–7
COMPLIANCE...........................................................................................................................................................1–8
CONFIGURATION MODE
changing settings.......................................................................................................................................4–9
description .....................................................................................................................................................4–5
navigation.......................................................................................................................................................6–5
programming............................................................................................................................................. 4–10
CONNECTION SETTING..................................................................................................................................... 4–13
CT SETTING............................................................................................................................................................ 4–11
CURRENT INPUTS
connections...................................................................................................................................................1–3
settings ......................................................................................................................................................... 4–11
specifications................................................................................................................................................1–6
D
DELTA CONNECTION
3-wire, 2 PTs, 3 CTs.................................................................................................................................. 3–15
3-wire, no PTs, 3 CTs............................................................................................................................... 3–14
background ...................................................................................................................................................2–4
phasors..................................................................................................................................................2–4, 2–5
setting............................................................................................................................................................ 4–13
DEMAND................................................................................................................................................................. 2–10
DIMENSIONS..................................................................................................................................................1–7, 3–1
DOWN BUTTON......................................................................................................................................................4–2
E
ENERGY......................................................................................................................................................... 2–8, 2–12
ENTER BUTTON.......................................................................................................................................................4–2
EPM 6000 MULTI-FUNCTION POWER METERING SYSTEM – USER GUIDE
INDEX–1
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INDEX
ENVIRONMENTAL SPECIFICATIONS...............................................................................................................1–7
F
FACEPLATE BUTTONS ..........................................................................................................................................4–2
FACEPLATE ELEMENTS ........................................................................................................................................4–2
FEATURES..................................................................................................................................................................1–1
FUSES..........................................................................................................................................................................3–8
G
GROUND CONNECTION......................................................................................................................................3–8
I
INSTALLATION
CT leads pass-through .............................................................................................................................3–6
CT leads terminated to meter ...............................................................................................................3–6
electrical..........................................................................................................................................................3–5
mechanical ....................................................................................................................................................3–1
precautions....................................................................................................................................................3–5
quick connect ...............................................................................................................................................3–7
voltage connections ..................................................................................................................................3–7
wiring................................................................................................................................................................3–9
IRDA
communications paths ......................................................................................................................... 3–19
description................................................................................................................................................... 3–19
L
LOAD BAR..................................................................................................................................................................4–3
M
MAIN MENU
description......................................................................................................................................................4–6
navigation.......................................................................................................................................................6–2
MEASURED VALUES..............................................................................................................................................1–4
MEMORY MAP..........................................................................................................................................................5–1
MENU BUTTON........................................................................................................................................................4–2
METER ADDRESS................................................................................................................................................. 4–14
METERING .......................................................................................................................................................1–4, 1–6
MODBUS
memory map ......................................................................................................................................5–1, 5–2
settings ......................................................................................................................................................... 4–15
MOUNTING
ANSI panel......................................................................................................................................................3–2
DIN panel ........................................................................................................................................................3–3
panel cutouts................................................................................................................................................3–2
N
NAVIGATION MAPS ...............................................................................................................................................6–1
INDEX–2
EPM 6000 MULTI-FUNCTION POWER METERING SYSTEM – USER GUIDE
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O
OPERATING MODE
navigation.......................................................................................................................................................6–3
programming............................................................................................................................................. 4–17
ORDER CODES.........................................................................................................................................................1–5
P
PANEL CUTOUTS....................................................................................................................................................3–2
PASSWORD ENTRY......................................................................................................................................4–7, 4–8
POWER .......................................................................................................................................................................2–8
POWER FACTOR .................................................................................................................................................. 2–13
POWER QUALITY ................................................................................................................................................. 2–17
POWER SUPPLY
connection .....................................................................................................................................................3–8
specifications................................................................................................................................................1–6
PROTOCOL............................................................................................................................................................. 4–16
PT SETTING ............................................................................................................................................................ 4–12
Q
QUICK CONNECT....................................................................................................................................................3–7
R
REGISTER MAP ........................................................................................................................................................5–1
RESET MODE
description .....................................................................................................................................................4–6
navigation.......................................................................................................................................................6–4
REVENUE METERING ............................................................................................................................................4–4
REVISION HISTORY................................................................................................................................................6–6
RIGHT BUTTON .......................................................................................................................................................4–2
RS485
specifications................................................................................................................................................1–7
wiring............................................................................................................................................................. 3–19
S
SCROLL FEATURE...................................................................................................................................................4–9
SPECIFICATIONS.....................................................................................................................................................1–6
STARTUP ....................................................................................................................................................................4–5
T
TYPE TESTING..........................................................................................................................................................1–8
U
UTILITY PEAK DEMAND .......................................................................................................................................1–3
V
VOLTAGE INPUTS
connections...................................................................................................................................................3–8
EPM 6000 MULTI-FUNCTION POWER METERING SYSTEM – USER GUIDE
INDEX–3
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INDEX
description......................................................................................................................................................1–3
settings ......................................................................................................................................................... 4–12
specifications................................................................................................................................................1–6
W
WARRANTY...............................................................................................................................................................6–8
WATT-HOUR ACCURACY TEST.........................................................................................................................4–4
WAVEFORM CAPTURE ...................................................................................................................................... 2–16
WIRING
current-only, dual-phase...................................................................................................................... 3–17
current-only, single-phase................................................................................................................... 3–18
current-only, three-phase.................................................................................................................... 3–16
delta ...................................................................................................................................................3–14, 3–15
description......................................................................................................................................................3–9
wye............................................................................................................................ 3–10, 3–11, 3–12, 3–13
WYE CONNECTION
4-wire, 2 PTs, 3 CTs, 2.5 element....................................................................................................... 3–13
4-wire, 3 PTs, 3 CTs, 3 element .......................................................................................................... 3–12
4-wire, no PTs, 3 CTs, 2.5 element.................................................................................................... 3–11
4-wire, no PTs, 3 CTs, 3 element........................................................................................................ 3–10
background....................................................................................................................................................2–2
phasors............................................................................................................................................................2–3
setting............................................................................................................................................................ 4–13
INDEX–4
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