Shark 200S User Manual V.1.11

Shark 200S User Manual V.1.11

Shark 200S

This page intentionally left blank.

Shark

®

200S Meter Installation and Operation Manual Version 1.11

Published by:

Electro Industries/GaugeTech

1800 Shames Drive

Westbury, NY 11590

All rights reserved. No part of this publication may be reproduced or transmitted in any form or by any means, electronic or mechanical, including photocopying, recording, or information storage or retrieval systems or any future forms of duplication, for any purpose other than the purchaser's use, without the expressed written permission of Electro Industries/GaugeTech.

© 2015 Electro Industries/GaugeTech

Shark® is a registered trademarks of Electro Industries/GaugeTech. The distinctive shapes, styles and overall appearances of the Shark® meters are trademarks of

Electro Industries/GaugeTech. Communicator EXT

TM

and V-Switch

TM

key are trademarks of Electro Industries/GaugeTech.

Windows® is either a registered trademark or trademark of Microsoft Corporation in the United States and/or other countries.

Modbus® is a registered trademark of Schneider Electric, licensed to the Modus

Organization, Inc.

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 i

This page intentionally left blank.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 ii

Customer Service and Support

Customer support is available 9:00 am to 4:30 pm, Eastern Standard Time, Monday through Friday. Please have the model, serial number and a detailed problem description available. If the problem concerns a particular reading, please have all meter readings available. When returning any merchandise to EIG, a return materials authorization number is required. For customer or technical assistance, repair or calibration, phone 516-334-0870 or fax 516-338-4741.

Product Warranty

Electro Industries/GaugeTech (EIG) warrants all products to be free from defects in material and workmanship for a period of four years from the date of shipment.

During the warranty period, we will, at our option, either repair or replace any product that proves to be defective.

To exercise this warranty, fax or call our customer-support department. You will receive prompt assistance and return instructions. Send the instrument, transportation prepaid, to EIG at 1800 Shames Drive, Westbury, NY 11590. Repairs will be made and the instrument will be returned.

This warranty does not apply to defects resulting from unauthorized modification, misuse, or use for any reason other than electrical power monitoring. The Shark

®

200S meter is not a user-serviceable product.

THIS WARRANTY IS IN LIEU OF ALL OTHER WARRANTIES, EXPRESSED

OR IMPLIED, INCLUDING ANY IMPLIED WARRANTY OF MERCHANTABIL-

ITY OR FITNESS FOR A PARTICULAR PURPOSE. ELECTRO INDUSTRIES/

GAUGETECH SHALL NOT BE LIABLE FOR ANY INDIRECT, SPECIAL OR

CONSEQUENTIAL DAMAGES ARISING FROM ANY AUTHORIZED OR

UNAUTHORIZED USE OF ANY ELECTRO INDUSTRIES/GAUGETECH

PRODUCT. LIABILITY SHALL BE LIMITED TO THE ORIGINAL COST OF

THE PRODUCT SOLD.

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 iii

Use Of Product for Protection

Our products are not to be used for primary over-current protection. Any protection feature in our products is to be used for alarm or secondary protection only.

Statement of Calibration

Our instruments are inspected and tested in accordance with specifications published by Electro Industries/GaugeTech. The accuracy and a calibration of our instruments are traceable to the National Institute of Standards and Technology through equipment that is calibrated at planned intervals by comparison to certified standards.

For optimal performance, EIG recommends that any metering device, including those manufactured by EIG, be verified for accuracy on a yearly interval using NIST traceable accuracy standards.

Disclaimer

The information presented in this publication has been carefully checked for reliability; however, no responsibility is assumed for inaccuracies. The information contained in this document is subject to change without notice.

Safety Symbols

In this manual, this symbol indicates that the operator must refer to an important WARNING or CAUTION in the operating instructions.

Please see Chapter 4 for important safety information regarding installation and hookup of the meter.

Dans ce manuel, ce symbole indique que l’opérateur doit se référer à un important

AVERTISSEMENT ou une MISE EN GARDE dans les instructions opérationnelles. Veuillez consulter le chapitre 4 pour des informations importantes relatives à l’installation et branchement du compteur.

The following safety symbols may be used on the meter itself:

Les symboles de sécurité suivante peuvent être utilisés sur le compteur même:

This symbol alerts you to the presence of high voltage, which can cause dangerous electrical shock.

Ce symbole vous indique la présence d’une haute tension qui peut provoquer une décharge électrique dangereuse.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 iv

This symbol indicates the field wiring terminal that must be connected to earth ground before operating the meter, which protects against electrical shock in case of a fault condition.

Ce symbole indique que la borne de pose des canalisations in-situ qui doit être branchée dans la mise à terre avant de faire fonctionner le compteur qui est protégé contre une décharge électrique ou un état défectueux.

This symbol indicates that the user must refer to this manual for specific WARNING or CAUTION information to avoid personal injury or damage to the product.

Ce symbole indique que l'utilisateur doit se référer à ce manuel pour AVERTISSEMENT ou MISE EN GARDE l'information pour éviter toute blessure ou tout endommagement du produit.

FCC Information

Regarding the wireless module:

• This device complies with Part 15 of the FCC rules. Operation is subject to the following two conditions: 1) this device may not cause harmful interference, and 2) this device must accept any interference received, including interference that may cause undesired operation.

• The antenna provided must not be replaced with an different type. Attaching a different antenna will void the FCC approval and the FCC ID can no longer be considered.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 v

About Electro Industries/GaugeTech

Founded in 1975 by engineer and inventor Dr. Samuel Kagan, Electro Industries/

GaugeTech changed the face of power monitoring forever with its first breakthrough innovation: an affordable, easy-to-use AC power meter.

Forty years since its founding, Electro Industries/GaugeTech, the leader in power monitoring and control, continues to revolutionize the industry with the highest quality, cutting edge power monitoring and control technology on the market today. An

ISO 9001:2008 certified company, EIG sets the industry standard for advanced power quality and reporting, revenue metering and substation data acquisition and control.

EIG products can be found on site at mainly all of today's leading manufacturers, industrial giants and utilities.

EIG products are primarily designed, manufactured, tested and calibrated at our facility in Westbury, New York.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 vi

Table of Contents

Table of Contents

Customer Service and Support

Product Warranty

Statement of Calibration

Disclaimer

FCC Information

About Electro Industries/GaugeTech

1: Three-Phase Power Measurement

1.1: Three-Phase System Configurations

1.1.1: Wye Connection

1.1.2: Delta Connection

1.1.3: Blondel’s Theorem and Three Phase Measurement

1.2: Power, Energy and Demand

1.3: Reactive Energy and Power Factor

1.4: Harmonic Distortion

1.5: Power Quality

2: Shark® 200S Submeter Overview and

Specifications

2.1: Hardware Overview

2.1.1: Model Number plus Option Numbers

2.1.2: Measured Values

2.1.3: Utility Peak Demand

2.2: Specifications iv iv iii iii iv v

1-1

1-8

1-12

1-14

1-17

1-1

1-1

1-4

1-6

2-1

2-1

2-3

2-3

2-5

2-5

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 TOC - 1

Table of Contents

2.3: Compliance

2.4: Accuracy

3: Mechanical Installation

3.1: Overview

3.2: Install the Base

3.2.1:Mounting Diagrams

3.3: Secure the Cover

4: Electrical Installation

4.1: Considerations When Installing Meters

4.2: Electrical Connections

4.3: Ground Connections

4.4: Voltage Fuses

4.5: Electrical Connection Diagrams 4-6

4.6: Extended Surge Protection for Substation Instrumentation 4-20

4-1

4-4

4-5

4-5

5: Communication Installation 5-1

5.1: Shark® 200S Communication

5.1.1: IrDA Port (Com 1)

5.1.1.1: USB to IrDA Adapter

5.1.2: RS485 Communication Com 2 (485 Option)

5.1.3: KYZ Output

5.1.4: Ethernet Connection

5.2: Meter Communication and Programming Overview

5.2.1: How to Connect to the Submeter

5-6

5-8

5-10

5-10

5-1

5-1

5-2

5-3

3-1

3-1

3-3

3-7

4-1

2-10

2-10

3-1

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 TOC - 2

Table of Contents

5.2.2: Shark® 200S Meter Device Profile Settings

6: Ethernet Configuration

6.1: Introduction

6.2: Setting up the Host PC to Communicate with

Shark® 200S Meter

6.2.1: Configuring the Host PC's Ethernet Adapter Using

Windows XP©

6.3: Setting up the Ethernet Module in the

Shark® 200S Meter

6.3.1: Configuring the Ethernet Module in the Shark® 200S

Meter using Windows XP© on the Host Computer

6.3.2: Example of Modifying Parameters in Groups 1, 6,

and 7

6.4: Network Module Hardware Initialization

7: Using the Submeter

7.1: Introduction

7.1.A: Understanding Submeter Face Elements

7.1.B: Understanding Submeter Face Buttons

7.2: Using the Front Panel

7.2.1: Understanding Startup and Default Displays

7.2.2: Using the Main Menu

7.2.3: Using Reset Mode

7.2.4: Entering a Password

7.2.5: Using Configuration Mode

7.2.5.1: Configuring the Scroll Feature

5-14

6-1

6-1

6-1

6-2

6-5

6-7

7-3

7-4

7-5

7-6

7-1

7-1

7-2

7-3

7-7

7-9

6-9

6-14

7-1

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 TOC - 3

Table of Contents

7.2.5.2: Configuring CT Setting

7.2.5.3: Configuring PT Setting

7.2.5.4: Configuring Connection Setting

7.2.5.5: Configuring Communication Port Setting

7.2.6: Using Operating Mode

7.3: Understanding the % of Load Bar

7.4: Performing Watt-Hour Accuracy Testing (Verification)

A: Shark® 200S Meter Navigation Maps

A.1: Introduction

A.2: Navigation Maps (Sheets 1 to 4)

B: Modbus Map and Retrieving Logs

B.1: Introduction

B.2: Modbus Register Map Sections

B.3: Data Formats

B.4: Floating Point Values

B.5: Retrieving Logs Using the Shark® 200S Meter's

Modbus Map

B.5.1: Data Formats

B.5.2: Shark® 200S Meter Logs

B.5.3: Block Definitions

B.5.4: Log Retrieval

B.5.4.1: Auto-Increment

B.5.4.2: Modbus Function Code 0x23

B.5.4.3: Log Retrieval Procedure

A-1

A-1

A-1

A-1

B-1

B-1

B-1

B-2

7-10

7-11

7-13

7-13

7-15

7-16

7-17

B-15

B-15

B-16

B-17

B-3

B-4

B-4

B-5

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 TOC - 4

Table of Contents

B.5.4.4: Log Retrieval Example

B.5.5: Log Record Interpretation

B.5.6: Examples

B.6: Important Note Concerning the Shark ® 200S

Meter's Modbus Map

B.6.1: Hex Representation

B.6.2: Decimal Representation

B.7: Modbus Register Map (MM-1 to MM-15)

C: DNP Mapping

C.1: Overview

C.2: Physical Layer

C.3: Data Link Layer

C.4: Application Layer

C.5: Error Reply

C.6: Shark® 200S Meter’s DNP Register Map

C.7: DNP Message Layouts

C.8: Internal Indication Bits

D: Using the USB to IrDA Adapter (CAB6490)

D.1: Introduction

D.2: Installation Procedures

B-20

B-29

B-37

D-1

D-1

D-1

C-3

C-3

C-6

C-9

C-1

C-1

C-1

C-2

B-40

B-40

B-40

B-41

C-1

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 TOC - 5

Table of Contents

This page intentionally left blank.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 TOC - 6

1: Three Phase Power Measurement

1: Three-Phase Power Measurement

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.

1.1: Three-Phase System Configurations

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.

1.1.1: 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 Y. Figure 1.1 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).

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 1 - 1

1: Three Phase Power Measurement

V

C

Phase 2

V

B

Phase 3

N

Phase 1

V

A

Figure 1.1: Three-phase Wye Winding

The three voltages are separated by 120 o

electrically. Under balanced load conditions the currents are also separated by 120 o

. However, unbalanced loads and other conditions can cause the currents to depart from the ideal 120 o separation. Threephase voltages and currents are usually represented with a phasor diagram. A phasor diagram for the typical connected voltages and currents is shown in Figure 1.2.

V

C

I

C

N

I

A

V

B

I

B

V

A

Figure 1.2: Phasor Diagram Showing Three-phase Voltages and Currents

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 1 - 2

1: Three Phase Power Measurement

The phasor diagram shows the 120 o

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. Table 1.1 shows the common voltages used in the United States for wyeconnected systems.

Phase to Ground Voltage Phase to Phase Voltage

120 volts

277 volts

2,400 volts

7,200 volts

7,620 volts

208 volts

480 volts

4,160 volts

12,470 volts

13,200 volts

Table 1: Common Phase Voltages on Wye Services

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 (as shown in

Figure 1.1). The neutral wire is typically tied to the ground or center point of the wye.

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 Table 1, 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.

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 1 - 3

1: Three Phase Power Measurement

1.1.2: Delta Connection

Delta-connected services may be fed with either three wires or four wires. In a threephase delta service the load windings are connected from phase-to-phase rather than from phase-to-ground. Figure 1.3 shows the physical load connections for a delta service.

V

C

Phase 2

Phase 3

V

B

Phase 1

V

A

Figure 1.3: 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.

Figure 1.4 shows the phasor relationships between voltage and current on a threephase 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.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 1 - 4

1: Three Phase Power Measurement

V

BC

I

C

V

CA

I

A

I

B

V

AB

Figure 1.4: Phasor Diagram, Three-Phase Voltages and Currents, Delta-Connected

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. Figure 1.5 shows the phasor diagram for the voltages in a three-phase, four-wire delta system.

V

C

V

CA

V

BC

N V

A

V

AB

V

B

Figure 1.5: Phasor Diagram Showing Three-phase Four-Wire Delta-Connected System

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 1 - 5

1: Three Phase Power Measurement

1.1.3: Blondel’s Theorem and Three Phase Measurement

In 1893 an engineer and mathematician named Andre E. Blondel set forth the first scientific basis for polyphase 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 wattmeters 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 accomplished 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 Blondel'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.

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, Blondel'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.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 1 - 6

1: Three Phase Power Measurement

Some digital meters measure 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 adds 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.

C

B

Phase B

Phase C

Node "n"

Phase A

A

N

Figure 1.6: Three-Phase Wye Load Illustrating Kirchhoff’s Law and Blondel’s Theorem

Blondel'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. Figure 1.6 shows a typical connection of a three-phase load applied to a three-phase, four-wire service. Kirchhoff's Law holds 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.

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 Blondel's Theorem- that we only need to measure the power in three of

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 1 - 7

1: Three Phase Power Measurement 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.

1.2: Power, Energy and Demand

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.

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 because it takes some amount of time to calculate the RMS values of voltage and current. But this time interval is kept small to preserve the instantaneous nature of power.

Energy is always based on 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 used.

Typically, electrical energy is measured in units of kilowatt-hours (kWh). A kilowatthour represents a constant load of one thousand watts (one kilowatt) for one hour.

Stated another way, if the power delivered (instantaneous watts) is measured as

1,000 watts and the load was served for a one hour time interval then the load would have absorbed one kilowatt-hour of energy. A different load may have a constant power requirement of 4,000 watts. If the load were served for one hour it would absorb four kWh. If the load were served for 15 minutes it would absorb ¼ of that total or one kWh.

Figure 1.7 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 will represent the power load for the one-minute increment of time. In real life the power value moves almost constantly.

The data from Figure 1.7 is reproduced in Table 2 to illustrate the calculation of energy. Since the time increment of the measurement is one minute and since we

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 1 - 8

1: Three Phase Power Measurement specified that the load is constant over that minute, we can convert the power reading to an equivalent consumed energy reading by multiplying the power reading times 1/

60 (converting the time base from minutes to hours).

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 1.7: Power Use over Time

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 1 - 9

1: Three Phase Power Measurement

Time

Interval

(minute)

Power

(kW)

Energy

(kWh)

Accumulated

Energy

(kWh)

50

70

80

60

70

80

50

60

60

70

70

30

50

40

55

13

14

15

9

10

11

12

7

8

5

6

3

4

1

2

0.50

0.83

0.67

0.92

1.00

1.00

1.17

1.17

1.00

1.17

1.33

0.83

0.83

1.17

1.33

Table 1.2: Power and Energy Relationship over Time

8.26

9.43

10.76

12.42

12.42

13.59

14.92

0.50

1.33

2.00

2.92

3.92

4.92

6.09

7.26

As in Table 1.2, the accumulated energy for the power load profile of Figure 1.7 is

14.92 kWh.

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 Figure 1.7) 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

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 1 - 10

1: Three Phase Power Measurement

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/hr or 59.68 kWd.

Note that the peak instantaneous value of power is 80 kW, significantly more than the demand value.

Figure 1.8 shows 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 number 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

Intervals (15 mins.)

7 8

Figure 1.8: Energy Use and Demand

As can be seen from this example, it is important to recognize the relationships between power, energy and demand in order to control loads effectively or to monitor use correctly.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 1 - 11

1: Three Phase Power Measurement

1.3: Reactive Energy and Power Factor

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 inphase component and the component that is at quadrature (angularly rotated 90 o

or perpendicular) to the voltage. Figure 1.9 shows a single-phase voltage and current and breaks the current into its in-phase and quadrature components.

I

R

V

0

I

X

I

Figure 1.9: 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 (I

R

) are combined to produce the real power or watts. The voltage and the quadrature current (I

X

) are combined to calculate the reactive power.

The quadrature current may be lagging the voltage (as shown in Figure 1.9) 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

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 1 - 12

1: Three Phase Power Measurement 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. 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, some utilities impose a penalty if the VAR content of the load rises above a specified value.

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:

Total PF = real power / apparent power = watts/VA

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

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 1 - 13

1: Three Phase Power Measurement harmonic distortion. Displacement power factor is calculated using the following equation:

Displacement PF = cos

T where

T

is the angle between the voltage and the current (see Fig. 1.9).

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.

1.4: Harmonic Distortion

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. Figure 1.10 shows a normal, sinusoidal current waveform. This example has no distortion.

1000

500

0

– 500

Time

– 1000

Figure 1.10: Nondistorted Current Waveform

Figure 1.11 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.

However, the waveform is not a smooth sinusoidal form as seen in Figure 1.10.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 1 - 14

1: Three Phase Power Measurement

1500

1000

500

0

– 500

– 1000

– 1500 a

2a t

Figure 1.11: Distorted Current Waveform

The distortion observed in Figure 1.11 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 disassembling the distorted waveform into a collection of higher frequency waveforms.

These higher frequency waveforms are referred to as harmonics. Figure 1.12 shows the content of the harmonic frequencies that make up the distortion portion of the waveform in Figure 1.11.

1000

500

0

– 500

Time

3rd harmonic

5th harmonic

7th harmonic

Total fundamental

Figure 1.12: Waveforms of the Harmonics

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 1 - 15

1: Three Phase Power Measurement

The waveforms shown in Figure 1.12 are not smoothed but do provide an indication of the impact of combining multiple harmonic frequencies together.

When harmonics are present it is important to remember that these quantities are operating at higher frequencies. Therefore, they do not always respond in the same manner as 60 Hz values.

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.

X

L

= j

Z

L and

X

C

= 1/j

Z

C

At 60 Hz, Z = 377; but at 300 Hz (5th harmonic) Z = 1,885. As frequency changes impedance changes and system impedance characteristics that are normal at 60 Hz may behave entirely differently in the presence of higher order harmonic waveforms.

Traditionally, the most common harmonics have been the low order, odd frequencies, such as the 3rd, 5th, 7th, and 9th. However newer, non-linear loads are introducing significant quantities of higher order harmonics.

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 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 a 480 volt 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.

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.

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 1 - 16

1: Three Phase Power Measurement

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.

1.5: Power Quality

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 mis-operation 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 Table

1.3.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 1 - 17

1: Three Phase Power Measurement

Cause Disturbance Type Source

Impulse transient

Oscillatory transient with decay

Transient voltage disturbance, sub-cycle duration

Transient voltage, sub-cycle duration

Under voltage/over voltage RMS voltage, steady state, multiple seconds or longer duration

Voltage flicker RMS voltage, steady state, repetitive condition

Lightning

Electrostatic discharge

Load switching

Capacitor switching

Line/cable switching

Capacitor switching

Load switching

Remote system faults Sag/swell

Interruptions

Harmonic distortion

RMS voltage, multiple cycle duration

RMS voltage, multiple seconds or longer duration

Steady state current or voltage, long-term duration

System protection

Circuit breakers

Fuses

Maintenance

Motor starting

Load variations

Load dropping

Intermittent loads

Motor starting

Arc furnaces

Non-linear loads

System resonance

Table 1.3: Typical Power Quality Problems and Sources

It is often assumed that power quality problems originate with the utility. While it is true that many 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.

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 1 - 18

2: Meter Overview and Specifications

2: Shark® 200S Submeter Overview and

Specifications

2.1: Hardware Overview

The Shark® 200S multifunction submeter is designed to measure revenue grade electrical energy usage and communicate that information via various communication media. The unit supports RS485, RJ45 wired Ethernet or IEEE 802.11 WiFi Ethernet connections. This allows the Shark® 200S submeter to be placed anywhere within an industrial or commercial facility and still communicate quickly and easily back to central software. The unit also has a front IrDA port that can be read and configured with an IrDA-equipped device, such as a laptop PC.

The unit is designed with advanced measurement capabilities, allowing it to achieve high performance accuracy. The Shark® 200S meter is specified as a

0.2% class energy meter (Current class 10 only) for billing applications. To verify the submeter’s performance and calibration, power providers use field test standards to verify that the unit’s energy measurements are correct. The Shark® 200S meter is a traceable revenue meter and contains a utility grade test pulse to verify rated accuracy.

The Shark® 200S meter has up to 2 MegaBytes* for datalogging. It offers three historical logs, a Limits (Alarm) log, and a System Events log.

*NOTE

: Because the memory is flash-based rather than NVRAM (non-volatile random-access memory), some sectors are reserved for overhead, erase procedures, and spare sectors for long-term wear reduction.

Shark® 200S meter features detailed in this manual are:

• 0.2% Class Revenue Certifiable Energy and Demand Submeter (Current Class 10 only)

• Meets ANSI C12.20 (0.2%) and IEC 62053-22 (0.2%) Classes

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 2-1

2: Meter Overview and Specifications

• Multifunction Measurement including Voltage, Current, Power, Frequency, Energy, etc.

• Three line 0.56” bright red LED Display

• 2 MegaBytes Memory for Datalogging

• Real Time Clock for Time-Stamping of Logs

• Line Frequency Time Synchronization

• 0.001% Frequency Measurement for Generating Stations

• Interval Energy Logging

• Percentage of Load Bar for Analog Meter Perception

• Modbus® RTU (over Serial) and Modbus® TCP (over Ethernet)

• Serial RS485 Communication

• Ethernet and Wireless Ethernet (WiFi)

• Easy to Use Faceplate Programming

• IrDA Port for Laptop PC Remote Read

• Direct Interface with Most Building Management Systems

The Shark® 200S submeter uses standard 5 or 1 Amp CTs (either split or donut). It surface mounts to any wall and is easily programmed in minutes. The unit is designed specifically for easy installation and advanced communication.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 2-2

2: Meter Overview and Specifications

2.1.1: Model Number plus Option Numbers

Model Frequency

Shark®

200S

Submeter

-50

50 Hz

System

-60

60 Hz

System

Current

Class

-10

5 Amp

Secondary

-2

1 Amp

Secondary

V-Switch

Pack

TM

-V33

Multifunction

Meter with 2

MegaBytes Datalogging memory

Power

Supply

Communication

Format

-D2

(90-400)

VAC

(100-

370)VDC

-485

RS485

-WIFI

Wireless and LAN

Based (Also configurable for

RS485)

Example:

Shark 200S - 60 - 10 - V33 - D2 - 485 which translates to a Shark® 200S submeter with a 60Hz system, Current class 10,

Default V-Switch

TM

, D2 power supply, and RS485 communication.

2.1.2: Measured Values

The Shark® 200S meter provides the following measured values all in real time and some additionally as average, maximum and minimum values.

Voltage L-N

Voltage L-L

Current per Phase

Current Neutral

Watts

VAR

VA

PF

+Watt-hr

Shark® 200S Meter Measured Values

Measured Values Real Time

X

X

X

X

X

X

X

X

X

Average

X

X

X

X

X

X

Maximum

X

X

X

X

X

X

X

Minimum

X

X

X

X

X

X

X

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 2-3

2: Meter Overview and Specifications

-Watt-hr

Watt-hr Net

+VAR-hr

-VAR-hr

VAR-hr Net

VA-hr

Frequency

Voltage Angles

Current Angles

% of Load Bar

Shark® 200S Meter Measured Values

Measured Values Real Time

X

X

X

X

X

X

X

X

X

X

Average Maximum

X

Minimum

X

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 2-4

2: Meter Overview and Specifications

2.1.3: Utility Peak Demand

The Shark® 200S meter provides user-configured Block (Fixed) window or Rolling window Demand. This feature allows you to set up a customized Demand profile.

Block window Demand is Demand used over a user-configured 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.

Utility Demand features can be used to calculate kW, kVAR, kVA and PF readings. All other parameters offer Max and Min capability over the user-selectable averaging period. Voltage provides an Instantaneous Max and Min reading which displays the highest surge and lowest sag seen by the meter.

2.2: Specifications

Power Supply

Range:

Power Consumption:

Voltage Inputs (Measurement Category III)

16 VA Maximum

Range:

Universal, (90 to 400)VAC

@50/60Hz or

(100 to 370)VDC

Supported hookups:

Universal, Auto-ranging up to

576VAC L-N, 721VAC L-L

3 Element Wye, 2.5 Element Wye,

2 Element Delta, 4 Wire Delta

1M Ohm/Phase Input Impedance:

Burden: 0.36VA/Phase Max at 600V,

0.0144VA/Phase at 120V

10VAC Pickup Voltage:

Connection: Screw terminal - #6 - 32 screws

See Figure 4.1

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 2-5

2: Meter Overview and Specifications

Input Wire Gauge:

Fault Withstand:

Reading:

AWG#16 - 26

Meets IEEE C37.90.1 (Surge

Withstand Capability)

Programmable Full Scale to any PT

Ratio

Current Inputs

Class 10:

Class 2:

Burden:

Pickup Current:

Connections:

Storage:

5A Nominal, 10 Amp Maximum

1A Nominal, 2 Amp Secondary

0.005VA Per Phase Max at 11 Amps

0.1% of Nominal

Screw terminal - #6-32 screws

(Diagram 4.1)

Current Surge Withstand:

Reading:

100A/10 seconds at 23 o

C

Programmable Full Scale to any CT

Ratio

Isolation

All Inputs and Outputs are galvanically isolated and tested to 2500VAC

Environmental Rating

(-20 to +70) o

C

Operating:

Humidity:

Faceplate Rating:

(-20 to +70) o

C to 95% RH Non-condensing

NEMA12 (Water Resistant)

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 2-6

2: Meter Overview and Specifications

Measurement Methods

Voltage, Current: True RMS

Power:

A/D Conversion:

Sampling at 400+ Samples per

Cycle on All Channels Measured

Readings Simultaneously

6 Simultaneous 24 bit Analog to

Digital Converters

Update Rate

Watts, VAR and VA: Every 6 cycles, e.g., 100 milliseconds (Ten times per second) @60Hz

All other parameters: Every 60 cycles, e.g, 1 second

@60Hz

Communication Format

1. RS485

2. IrDA Port through Face Plate

Protocols:

Com Port Baud Rate:

Com Port Address:

Data Format:

Modbus RTU, Modbus ASCII, DNP

3.0, Modbus TCP (for Ethernetenabled)

RS485 Only: 1200, 2400, 4800*;

All Com Ports: 9600 to 57600 bps

001-247

8 Bit, No Parity (RS485: also Even or Odd Parity*)

*With Runtime Firmware Version 26 or higher

Wireless Ethernet (Optional)

802.11b Wireless or

10/100BaseT Ethernet

Wireless Security

Modbus TCP Protocol

WiFi or RJ45 Connection

64 or 128 bit WEP; WPA; or WPA2

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 2-7

2: Meter Overview and Specifications

Mechanical Parameters

Dimensions: (H7.9 x W7.6 x D3.2) inches,

(H200.7 x W193.0 x D81.3) mm

4 pounds/1.814 kilograms Weight:

KYZ/RS485 Port Specifications

RS485 Transceiver; meets or exceeds EIA/TIA-485 Standard:

Type:

Min. Input Impedance:

Max. Output Current:

Two-wire, half duplex

96k

ƻ

±60mA

Wh Pulse

KYZ output contacts (and infrared LED light pulses through face plate): (See Section

7.4 for Kh values.)

Pulse Width:

Full Scale Frequency:

Contact type:

Relay type:

Peak switching voltage:

Continuous load current:

Peak load current:

On resistance, max.:

Leakage current:

Isolation:

Reset State:

90ms

~3Hz

Solid State – SPDT (NO – C – NC)

Solid state

DC ±350V

120mA

350mA for 10ms

35

ƻ

1

μ

[email protected]

AC 3750V

(NC - C) Closed; (NO - C) Open

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 2-8

2: Meter Overview and Specifications

Infrared LED:

Peak Spectral Wavelength:

Reset State:

940nm

Off

Internal Schematic: Output Timing:

NC

C

NO

LED

OFF

90ms

LED

ON

T

[

s

]

3600

˜

Kh

P

ª

«

¬

Watthour

[

Watt pulse

]

IR LED Light Pulses

Through face plate

LED

OFF

º

»

¼

P

[

Watt

] - Not a scaled value

Kh

– See Section 7-4 for values

90ms

LED

ON

Internal Schematic: Output Timing:

KYZ output

Contact States

Through Backplate

LED

OFF

NC NC NC NC NC

C C C C C

NO NO NO NO NO

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 2-9

2: Meter Overview and Specifications

2.3: Compliance

• IEC 62053-22 (0.2% Accuracy)

• ANSI C12.20 (0.2% Accuracy)

• ANSI (IEEE) C37.90.1 Surge Withstand

• ANSI C62.41 (Burst)

• EN61000-6-2 Immunity for Industrial Environments: 2005

• EN61000-6-4 Emission Standards for Industrial Environments: 2007

• EN61326-1 EMC Requirements: 2006

• Certified to UL 61010-1 and CSA C22.2 No. 61010-1, UL File: E250818

• CE Compliant

2.4: Accuracy

For 23 o

C, 3 Phase balanced Wye or Delta load, at 50 or 60 Hz (as per order), 5A

(Class 10) nominal unit:

Parameter

Voltage L-N [V]

Voltage L-L [V]

Accuracy

0.1% of reading

2

0.1% of reading

Current Phase [A]

0.1% of reading

1

Current Neutral (calculated)

[A]

2.0% of Full Scale

1

Active Power Total [W]

0.2% of reading

1,2

Active Energy Total [Wh]

0.2% of reading

1,2

Reactive Power Total [VAR] 0.2% of reading

1,2

Reactive Energy Total

[VARh]

0.2% of reading

1,2

Apparent Power Total [VA] 0.2% of reading

1,2

Apparent Energy Total [VAh]0.2% of reading

1,2

Accuracy Input Range

(69 to 480)V

(120 to 600)V

(0.15 to 5)A

(0.15 to 5)A @ (45 to 65)Hz

(0.15 to 5)A @ (69 to 480)V

@ +/- (0.5 to 1) lag/lead PF

(0.15 to 5)A @ (69 to 480)V

@ +/- (0.5 to 1) lag/lead PF

(0.15 to 5)A @ (69 to 480)V

@ +/- (0 to 0.8) lag/lead PF

(0.15 to 5)A @ (69 to 480)V

@ +/- (0 to 0.8) lag/lead PF

(0.15 to 5)A @ (69 to 480)V

@ +/- (0.5 to 1) lag/lead PF

(0.15 to 5)A @ (69 to 480)V

@ +/- (0.5 to 1) lag/lead PF

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 2-10

2: Meter Overview and Specifications

Power Factor

Frequency

Load Bar

0.2% of reading

1,2

+/- 0.001Hz

+/- 1 segment

1

(0.15 to 5)A @ (69 to 480)V

@ +/- (0.5 to 1) lag/lead PF

(45 to 65)Hz

(0.005 to 6)A

1

For 2.5 element programmed units, degrade accuracy by an additional 0.5% of

reading.

• For 1A (Class 2) Nominal, degrade accuracy by an additional 0.5% of reading.

• For 1A (Class 2) Nominal, the input current range for Accuracy specification is

20% of the values listed in the table.

2

For unbalanced voltage inputs where at least one crosses the 150V auto-scale

threshold (for example, 120V/120V/208V system), degrade accuracy by additional

0.4%.

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 2-11

2: Meter Overview and Specifications

This page intentionally left blank.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 2-12

3: Mechanical Installation

3: Mechanical Installation

3.1: Overview

The Shark® 200S meter can be installed on any wall. See Chapter 4 for wiring diagrams.

Mount the meter in a dry location, which is free from dirt and corrosive substances.

Recommended Tools for Shark® 200S Installation

• #2 Phillips screwdriver

• Wire cutters

WARNING!

During normal operation of the Shark® 200S meter, dangerous voltages flow through many parts of the meter, including: Terminals and any connected CTs (Current Transformers) and PTs (Potential Transformers), all I/O Modules (Inputs and Outputs) and their circuits. All

Primary and Secondary circuits can, at times, produce lethal voltages and

currents. Avoid contact with any current-carrying surfaces.

Before performing ANY

work on the meter, make sure the meter is powered down and all connected

circuits are de-energized.

AVERTISSEMENT!

Pendant le fonctionnement normal du compteur Shark® 200S des

tensions dangereuses suivant de nombreuses pièces, notamment, les bornes et tous

les transformateurs de courant branchés, les transformateurs de tension, toutes les

sorties, les entrées et leurs circuits. Tous les circuits secondaires et primaires peuvent

parfois produire des tensions de létal et des courants. Évitez le contact avec les

surfaces sous tensions.

Avant de faire un travail dans le compteur, assurez-vous

d’éteindre l’alimentation et de mettre tous les circuits branchés hors tension.

3.2: Install the Base

1. Determine where you want to install the submeter.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 3 - 1

3: Mechanical Installation

2.

With the submeter power off

, open the top of the submeter. Use the front cover support to keep the cover open as you perform the installation (see Figure

3.1).

Front

Cover

Support

Figure 3.1: Shark Submeter with Cover Open

CAUTIONS!

• Remove the antenna before opening the unit.

• Only use the front cover support if you are able to open the front cover to the extent that you can fit the front cover support into its base.

DO NOT

rest the front cover support on the inside of the meter, even for a short time - by doing so, you may damage components on the board assembly.

3. Find the 4 Installation Slots and insert screws through each slot into the wall or panel.

4. Fasten securely - DO NOT overtighten.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 3 - 2

3.2.1:Mounting Diagrams

v

CM

3: Mechanical Installation v

CM v

CM

-/5.4).'0,!4% v

CM

Figure 3.2: Mounting Plate Dimensions v

CM

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 3 - 3

3: Mechanical Installation v

CM

!NTENNA,ENGTHvCM

Figure 3.3: Front Dimensions v

CM

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 3 - 4

3: Mechanical Installation v

CM

Figure 3.4: Side Dimensions

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 3 - 5

3: Mechanical Installation

12”/

30.4cm

Figure 3.5: Open Cover Dimensions w

DN

$57PMUBHF$POUSPM1PXFS(SPVOE

5ISPVHI)FSF

$PNNVOJDBUJPOT,:;5ISPVHI)FSF

Figure 3.6: Bottom View with Access Holes

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 3 - 6

3: Mechanical Installation

3.3: Secure the Cover

1. Close the cover, making sure that power and communications wires exit the submeter through the openings at the base (see Figure 3.6).

CAUTION!

To avoid damaging components on the board assembly, make sure the front cover support is in the upright position before closing the front cover.

2. Using the 3 enclosed screws, secure the cover to the base in three places - DO

NOT overtighten (you may damage the cover).

3. The unit can be sealed after the front cover is closed. To seal the unit, thread the seal tag through the housing located between the bottom access holes (see figures

3.6 and 3.7).

4. Reattach the antenna, if applicable.

Closed

Screw

Lockable Revenue Seal

Figure 3.7: Submeter with Closed Cover

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 3 - 7

3: Mechanical Installation

This page intentionally left blank.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 3 - 8

4: Electrical Installation

4: Electrical Installation

4.1: Considerations When Installing Meters

Installation of the Shark® 200S meter must be performed only by 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.

WARNING! During normal operation of the Shark® 200S meter, dangerous voltages flow through many parts of the meter, including: Terminals and any connected CTs

(Current Transformers) and PTs (Potential Transformers), all I/O Modules (Inputs and

Outputs) and their circuits. All Primary and Secondary circuits can, at times, produce lethal voltages and currents. Avoid contact with any current-carrying surfaces.

Before performing ANY work on the meter, make sure the meter is powered down and all connected circuits are de-energized.

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 HIPOT/Dielectric test any Outputs, Inputs or Communications terminals.

EIG requires the use of Fuses for voltage leads and power supply and Shorting Blocks to prevent hazardous voltage conditions or damage to CTs, if the meter needs to be removed from service. CT grounding is optional, but recommended.

NOTE: The current inputs are only to be connected to external current transformers provided by the installer. The CT's shall be Approved or Certified and rated for the current of the meter used.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 4-1

4: Electrical Installation

L'installation des compteurs de Shark® 200S doit être effectuée seulement par un personnel qualifié qui suit les normes relatives aux précautions de sécurité pendant toute la procédure. Le personnel doit avoir la formation appropriée et l'expérience avec les appareils de haute tension. Des gants de sécurité, des verres et des vêtements de protection appropriés sont recommandés.

AVERTISSEMENT! Pendant le fonctionnement normal du compteur Shark® 200S des tensions dangereuses suivant de nombreuses pièces, notamment, les bornes et tous les transformateurs de courant branchés, les transformateurs de tension, toutes les sorties, les entrées et leurs circuits. Tous les circuits secondaires et primaires peuvent parfois produire des tensions de létal et des courants. Évitez le contact avec les surfaces sous tensions. Avant de faire un travail dans le compteur, assurez-vous d'éteindre l'alimentation et de mettre tous les circuits branchés hors tension.

Ne pas utiliser les compteurs ou sorties d'appareil pour une protection primaire ou capacité de limite d'énergie. Le compteur peut seulement être utilisé comme une protection secondaire.

Ne pas utiliser le compteur pour application dans laquelle une panne de compteur peut causer la mort ou des blessures graves.

Ne pas utiliser le compteur ou pour toute application dans laquelle un risque d'incendie est susceptible.

Toutes les bornes de compteur doivent être inaccessibles après l'installation.

Ne pas appliquer plus que la tension maximale que le compteur ou appareil relatif peut résister. Référez-vous au compteur ou aux étiquettes de l'appareil et les spécifications de tous les appareils avant d'appliquer les tensions. Ne pas faire de test

HIPOT/diélectrique, une sortie, une entrée ou un terminal de réseau.

Les entrées actuelles doivent seulement être branchées aux transformateurs externes actuels.

EIG nécessite l'utilisation de les fusibles pour les fils de tension et alimentations électriques, ainsi que des coupe-circuits pour prévenir les tensions dangereuses ou endommagements de transformateur de courant si l'unité Shark® 200S doit être enlevée du service. Un côté du transformateur de courant doit être mis à terre.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 4-2

4: Electrical Installation

NOTE: les entrées actuelles doivent seulement être branchées dans le transformateur externe actuel par l'installateur. Le transformateur de courant doit être approuvé ou certifié et déterminé pour le compteur actuel utilisé.

IMPORTANT!

IF THE EQUIPMENT IS USED IN A MANNER NOT SPECIFIED

BY THE MANUFACTURER, THE PROTECTION PROVIDED BY

THE EQUIPMENT MAY BE IMPAIRED.

• THERE IS NO REQUIRED PREVENTIVE MAINTENANCE OR INSPEC-

TION NECESSARY FOR SAFETY. HOWEVER, ANY REPAIR OR MAIN-

TENANCE SHOULD BE PERFORMED BY THE FACTORY.

DISCONNECT DEVICE: The following part is considered the equipment disconnect device. A SWITCH OR CIRCUIT-BREAKER SHALL BE

INCLUDED IN THE END-USE EQUIPMENT OR BUILDING INSTALLA-

TION. THE SWITCH SHALL BE IN CLOSE PROXIMITY TO THE EQUIP-

MENT AND WITHIN EASY REACH OF THE OPERATOR. THE SWITCH

SHALL BE MARKED AS THE DISCONNECTING DEVICE FOR THE

EQUIPMENT.

IMPORTANT! SI L'ÉQUIPEMENT EST UTILISÉ D'UNE FAÇON

NON SPÉCIFIÉE PAR LE FABRICANT, LA PROTECTION

FOURNIE PAR L'ÉQUIPEMENT PEUT ÊTRE ENDOMMAGÉE.

NOTE: Il N'Y A AUCUNE MAINTENANCE REQUISE POUR LA PRÉVENTION OU INSPEC-

TION NÉCESSAIRE POUR LA SÉCURITÉ. CEPENDANT, TOUTE RÉPARATION OU MAIN-

TENANCE DEVRAIT ÊTRE RÉALISÉE PAR LE FABRICANT.

DÉBRANCHEMENT DE L'APPAREIL : la partie suivante est con-

sidérée l'appareil de débranchement de l'équipement.

UN INTERRUPTEUR OU UN DISJONCTEUR DEVRAIT ÊTRE INCLUS

DANS L'UTILISATION FINALE DE L'ÉQUIPEMENT OU L'INSTALLATION.

L'INTERRUPTEUR DOIT ÊTRE DANS UNE PROXIMITÉ PROCHE DE

L'ÉQUIPEMENT ET A LA PORTÉE DE L'OPÉRATEUR. L'INTERRUPTEUR DOIT AVOIR LA

MENTION DÉBRANCHEMENT DE L'APPAREIL POUR L'ÉQUIPEMENT.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 4-3

4: Electrical Installation

4.2: Electrical Connections

All wiring for the Shark® 200S is done through the front of the unit (lifting the cover with the power to the unit OFF) so that the unit can be surface mounted. Connecting cables exit the unit via two openings in the base plate (see figures 3.5 and 4.1).

WARNING! During normal operation of the Shark® 200S meter, dangerous voltages flow through many parts of the meter, including:

Terminals and any connected CTs (Current Transformers) and PTs

(Potential Transformers), all I/O Modules (Inputs and Outputs) and their circuits. All Primary and Secondary circuits can, at times, produce lethal voltages and currents. Avoid contact with any current-carrying surfaces.

Before performing ANY work on the meter, make sure the meter is powered down and all connected circuits are de-energized.

AVERTISSEMENT! Pendant le fonctionnement normal du compteur Shark® 200S des tensions dangereuses suivant de nombreuses pièces, notamment, les bornes et tous les transformateurs de courant branchés, les transformateurs de tension, toutes les sorties, les entrées et leurs circuits. Tous les circuits secondaires et primaires peuvent parfois produire des tensions de létal et des courants. Évitez le contact avec les surfaces sous tensions. Avant de faire un travail dans le compteur, assurez-vous d'éteindre l'alimentation et de mettre tous les circuits branchés hors tension.

CAUTION! DO NOT over-torque screws.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 4-4

4: Electrical Installation

Wireless Ethernet Connection

Current

Inputs

Electronic Circuits

Ia Ia Ib Ib Ic Ic

(+) (-) (+) (-) (+) (-)

Va Vb Vc Vn L1 L2 PE

Z K Y + - SH

Voltage

Inputs

Access Holes for

Wiring

Do not over-torque screws!

Power Supply

Inputs (Inputs are unipolar)

Ethernet, RJ45

Jack

RS485 Output

(Do not put the

Voltage on these terminals!)

RS-485

KYZ Pulse

Output

Figure 4.1: Submeter Connections

4.3: Ground Connections

The meter's Ground Terminal (PE) should be connected directly to the installation's protective earth ground.

4.4: Voltage Fuses

EIG requires the use of fuses on each of the sense voltages and on the control power.

• Use a 0.1 Amp fuse on each Voltage input.

• Use a 3 Amp fuse on the power supply.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 4-5

4: Electrical Installation

4.5: Electrical Connection Diagrams

Choose the diagram that best suits your application. Make sure the CT polarity is correct.

1. Three Phase, Four-Wire System Wye with Direct Voltage, 3 Element a. Dual Phase Hookup b. Single Phase Hookup

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 (No PTs, 2 CTs)

6. Three-Phase, Three-Wire Delta with Direct Voltage (No PTs, 3 CTs)

7. Three-Phase, Three-Wire Delta with 2 PTs, 2 CTs

8. Three-Phase, Three-Wire Delta with 2 PTs, 3 CTs

9. Current Only Measurement (Three Phase)

10. Current Only Measurement (Dual Phase)

11. Current Only Measurement (Single Phase)

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 4-6

1. Service: WYE, 4-Wire with No PTs, 3 CTs

N

C

LINE

B

A

4: Electrical Installation

Electronic Circuits

CT

Shorting

Block

Earth Ground

Ia+ IaIb+ IbIc+ Ic-

CN2

CN1

Va Vb Vc Vref L1 L2 PE

FUSES

3 x 0.1A

Power

Supply

Connection

N C B

LOAD

A

Select: "3 EL WYE" (3 Element Wye) in Meter Programming setup.

C

B

A

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 4-7

4: Electrical Installation

1a. Dual Phase Hookup

N

C

LINE

B

A

Electronic Circuits

CT

Shorting

Block

Earth Ground

Ia+ IaIb+ IbIc+ Ic-

CN2

CN1

Va Vb Vc Vref L1 L2 PE

FUSES

2x 0.1A

Power

Supply

Connection

N C B

LOAD

A

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 4-8

4: Electrical Installation

1b. Single Phase Hookup

N

C

LINE

B

A

Electronic Circuits

CT

Shorting

Block

Earth Ground

Ia+ IaIb+ IbIc+ Ic-

CN2

CN1

Va Vb Vc Vref L1 L2 PE

FUSE

0.1A

Power

Supply

Connection

N C B

LOAD

A

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 4-9

4: Electrical Installation

2. Service: 2.5 Element WYE, 4-Wire with No PTs, 3 CTs

N

C

LINE

B A

Electronic Circuits

CT

Shorting

Block

Earth Ground

Ia+ IaIb+ IbIc+ Ic-

CN2

CN1

Va Vb Vc Vref L1 L2 PE

FUSES

2 x 0.1A

Power

Supply

Connection

N C B

LOAD

A

Select: "2.5 EL WYE" (2.5 Element Wye) in Meter Programming setup.

C

A

B

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 4-10

3. Service: WYE, 4-Wire with 3 PTs, 3 CTs

N C

LINE

B

A

4: Electrical Installation

Electronic Circuits

CT

Shorting

Block

Earth Ground

Ia+ IaIb+ IbIc+ Ic-

CN2

CN1

Va Vb Vc Vref L1 L2 PE

FUSES

3 x 0.1A

Power

Supply

Connection

Earth Ground

N C B

LOAD

A

Select: "3 EL WYE" (3 Element Wye) in Meter Programming setup.

C

A

B

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 4-11

4: Electrical Installation

4. Service: 2.5 Element WYE, 4-Wire with 2 PTs, 3 CTs

N C

LINE

B

A

Electronic Circuits

CT

Shorting

Block

Earth Ground

Ia+ IaIb+ IbIc+ Ic-

CN2

CN1

Va Vb Vc Vref L1 L2 PE

FUSES

2 x 0.1A

Power

Supply

Connection

Earth Ground

N C B

LOAD

A

Select: "2.5 EL WYE" (2.5 Element Wye) in Meter Programming setup.

C

B

A

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 4-12

5. Service: Delta, 3-Wire with No PTs, 2 CTs

C

LINE

B

A

4: Electrical Installation

Electronic Circuits

CT

Shorting

Block

Earth Ground

Ia+ IaIb+ IbIc+ Ic-

CN2

CN1

Va Vb Vc Vref L1 L2 PE

FUSES

3 x 0.1A

Power

Supply

Connection

C B

LOAD

A

Select: "2 Ct dEL" (2 CT Delta) in Meter Programming setup.

C C

B A B

Not Connected to Meter

A

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 4-13

6. Service: Delta, 3-Wire with No PTs, 3 CTs

C

LINE

B

A

4: Electrical Installation

Electronic Circuits

CT

Shorting

Block

Earth Ground

Ia+ IaIb+ IbIc+ Ic-

CN2

CN1

Va Vb Vc Vref L1 L2 PE

FUSES

3 x 0.1A

Power

Supply

Connection

C B

LOAD

A

Select: "2 Ct dEL" (2 CT Delta) in Meter Programming setup.

C C

B A B

Not Connected to Meter

A

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 4-14

7. Service: Delta, 3-Wire with 2 PTs, 2 CTs

C

LINE

B

A

4: Electrical Installation

Electronic Circuits

CT

Shorting

Block

Earth Ground

Ia+ IaIb+ IbIc+ Ic-

CN2

CN1

Va Vb Vc Vref L1 L2 PE

FUSES

2 x 0.1A

Power

Supply

Connection

Earth Ground

C B

LOAD

A

Select: "2 Ct dEL" (2 CT Delta) in Meter Programming setup.

C C

B A B

Not Connected to Meter

A

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 4-15

8. Service: Delta, 3-Wire with 2 PTs, 3 CTs

C

LINE

B

A

4: Electrical Installation

Electronic Circuits

CT

Shorting

Block

Earth Ground

Ia+ IaIb+ IbIc+ Ic-

CN2

CN1

Va Vb Vc Vref L1 L2 PE

FUSES

2 x 0.1A

Power

Supply

Connection

Earth Ground

C B

LOAD

A

Select: "2 Ct dEL" (2 CT Delta) in Meter Programming setup.

C C

B A B

Not Connected to Meter

A

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 4-16

4: Electrical Installation

9. Service: Current Only Measurement (Three Phase)

N

LINE

C B

A

Electronic Circuits

CT

Shorting

Block

Earth Ground

Ia+ IaIb+ IbIc+ Ic-

CN2

CN1

Va Vb Vc Vref L1 L2 PE

FUSE

0.1A

20VAC

Minimum

Power

Supply

Connection

N C B

LOAD

A

Select: "3 EL WYE" (3 Element Wye) in Meter Programming setup.

NOTE: Even if the meter is used for only Amp readings, the unit requires a Volts AN reference. Please make sure that the Voltage input is attached to the meter. AC

Control Power can be used to provide the reference signal.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 4-17

4: Electrical Installation

10. Service: Current Only Measurement (Dual Phase)

N

LINE

B

A

Electronic Circuits

CT

Shorting

Block

Earth Ground

Ia+ IaIb+ IbIc+ Ic-

CN2

CN1

Va Vb Vc Vref L1 L2 PE

FUSE

0.1A

20VAC

Minimum

Power

Supply

Connection

N B

LOAD

A

Select: "3 EL WYE" (3 Element Wye) in Meter Programming setup.

NOTE: Even if the meter is used for only Amp readings, the unit requires a Volts AN reference. Please make sure that the Voltage input is attached to the meter. AC

Control Power can be used to provide the reference signal.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 4-18

4: Electrical Installation

11. Service: Current Only Measurement (Single Phase)

N

LINE

A

Electronic Circuits

CT

Shorting

Block

Earth Ground

Ia+ IaIb+ IbIc+ Ic-

CN2

CN1

Va Vb Vc Vref L1 L2 PE

FUSE

0.1A

20VAC

Minimum

Power

Supply

Connection

N A

LOAD

Select: "3 EL WYE" (3 Element Wye) in Meter Programming setup.

NOTE: Even if the meter is used for only Amp readings, the unit requires a Volts AN reference. Please make sure that the Voltage input is attached to the meter. AC

Control Power can be used to provide the reference signal.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 4-19

4: Electrical Installation

4.6: Extended Surge Protection for Substation Instrumentation

EIG offers a surge protector for applications with harsh electrical conditions. The surge protector is EI-MSB10-400 and it can be ordered from EIG’s webstore: www.electroind.com/store.

The EI-MSB10-400 surge protector is designed to protect sensitive equipment from the damaging effects of lightning strikes and/or industrial switching surges in single phase AC networks up to 320VAC (L-N / L-G), and DC networks up to 400 VDC. The protectors are ideal for metering systems, RTUs, PLCs and protective relays. They are used specifically to extend the life and increase reliability of critical control apparatus.

For best protection, it is recommended to use two protectors. These will protect the instrument on the line inputs and on the reference input to ground. The protectors have LED indication to annunciate when the protection has worn out.

The EI-MSB10-400 is connected by wires in parallel with the network to be protected.

It can be easily mounted on a wall or plate with self-adhesive tape.

See the wiring diagram below.

PE

L (+)

N (-)

N (-)

BREAKER

BREAKER

L/N

L/N

L/N

L/N

L/N

L/N

L/N

L/N

FUSE

FUSE

GND

GND

L (+)

L (+)

N (-)

N (-)

Vref

Vref

Substation

Instrumentatio

Va

Vb

Vb

Vc

Vc

Figure 4.2: Wiring Schematic for Extended Surge Suppression

Suitable for Substation Instrumentation

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 4-20

5: Communication Installation

5: Communication Installation

5.1: Shark® 200S Communication

The Shark® 200S submeter provides two independent communication ports plus a

KYZ pulse output. The first port, Com 1, is an IrDA Port, which uses Modbus ASCII.

The second port, Com 2, provides RS485 or RJ45 Ethernet or WiFi Ethernet communication (see Chapter 6 for Ethernet communication).

5.1.1: IrDA Port (Com 1)

The Com 1 IrDA port is located on the face of the submeter. The IrDA Port allows the unit to be set up and programmed with any device capable of IrDA communication, such as an IrDA-equipped laptop PC or a USB/IrDA wand (such as the USB to IrDA

Adapter [CAB6490] described in Appendix D).

IrDA port settings are

Address: 1

Baud Rate: 57600 Baud

Protocol: Modbus ASCII

Figure 5.1: IrDA Communication

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-1

5.1.1.1: USB to IrDA Adapter

PC

USB

Port

USB

Extension

Cable

USB to IrDA Adapter

5: Communication Installation

IrDA

Enabled

Device

IrDA

Module

Figure 5.2: USB to IrDA Adapter

The USB to IrDA Adapter (CAB6490) enables IrDA wireless data communication through a standard USB port. The adapter is powered through the USB bus and does not require any external power adapter. The effective data transmission distance is 0 to .3 meters (approximately 1 foot).

The USB to IrDA Adapter enables wireless data transfer between a PC and the submeter. The adapter can also be used with other IrDA-compatible devices. The adapter is fully compatible with IrDA 1.1 and USB 1.1 specifications.

System Requirements

• IBM PC Pentium based computer

• 2 Gigabytes of RAM preferable

• Available USB port

• CD-ROM drive

• Windows® 98, Windows® XP, or Windows® 7 Operating Systems

See Appendix D for instructions on using the USB to IrDA Adapter. You can order

CAB6490 from EIG’s webstore: www.electroind.com/store. Select Cables and Accessories from the list on the left side of the screen.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-2

5: Communication Installation

5.1.2: RS485 Communication Com 2 (485 Option)

The Shark® 200S submeter's RS485 port RS485 port uses standard 2-Wire, half duplex architecture. The RS485 connector is located on the front of the meter, under the cover. A connection can easily be made to a Master device or to other slave devices, as shown below.

WARNING!

During normal operation of the Shark® 200S meter, dangerous voltages flow through many parts of the meter, including:

Terminals and any connected CTs (Current Transformers) and PTs (Potential

Transformers), all I/O Modules (Inputs and Outputs) and their circuits. All

Primary and Secondary circuits can, at times, produce lethal voltages and currents.

Avoid contact with any current-carrying surfaces.

Before performing ANY work on

the meter, make sure the meter is powered down and all connected circuits

are de-energized.

AVERTISSEMENT!

Pendant le fonctionnement normal du compteur Shark® 200S des tensions dangereuses suivant de nombreuses pièces, notamment, les bornes et tous les transformateurs de courant branchés, les transformateurs de tension, toutes les sorties, les entrées et leurs circuits. Tous les circuits secondaires et primaires peuvent parfois produire des tensions de létal et des courants. Évitez le contact avec les surfaces sous tensions.

Avant de faire un travail dans le compteur, assurezvous d'éteindre l'alimentation et de mettre tous les circuits branchés hors tension.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-3

5: Communication Installation

NOTE:

Care should be taken to connect + to + and - to - connections.

Wireless Ethernet Connection

Electronic Circuits

Ia Ia Ib Ib Ic Ic

(+) (-) (+) (-) (+) (-)

Va Vb Vc Vn L1 L2 PE

Z K Y + - SH

JP2: Must be in

position 1-2 for

RS485

RS485

To Other

Devices

Pulse Contacts

The Shark® 100S submeter's RS485 connection can be programmed with the buttons on the face of the meter or by using Communicator EXT

TM

software.

Standard RS485 Port Settings*

Address: 001 to 247

Baud Rate: 9600, 19200, 38400 or 57600 Baud

Protocol: Modbus RTU, Modbus ASCII, or DNP 3.0

* With Runtime Firmware Version 26 or higher, Baud Rate settings of 1200, 2400, and

4800 and Parity settings (Even, Odd, None) are also available.

IMPORTANT!

The position of Jumper 2 (JP2) must be set for either RS485 or Ethernet communication. See the figure on the next page. You put the jumper on positions

2 and 3 for LAN (Ethernet) communication, and on 1 and 2 for RS485 communication.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-4

5: Communication Installation

JP2

LAN/

RS485

Setting

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-5

5: Communication Installation

5.1.3: KYZ Output

The KYZ pulse output provides pulsing energy values that verify the submeter's readings and accuracy. The KYZ Pulse Output is located on the face of the meter, under the cover and just below the RS485 connection (see figure on the next page).

WARNING!

During normal operation of the Shark® 200S meter, dangerous voltages flow through many parts of the meter, including:

Terminals and any connected CTs (Current Transformers) and PTs (Potential

Transformers), all I/O Modules (Inputs and Outputs) and their circuits. All

Primary and Secondary circuits can, at times, produce lethal voltages and currents.

Avoid contact with any current-carrying surfaces.

Before performing ANY work on

the meter, make sure the meter is powered down and all connected circuits

are de-energized.

AVERTISSEMENT!

Pendant le fonctionnement normal du compteur Shark® 200S des tensions dangereuses suivant de nombreuses pièces, notamment, les bornes et tous les transformateurs de courant branchés, les transformateurs de tension, toutes les sorties, les entrées et leurs circuits. Tous les circuits secondaires et primaires peuvent parfois produire des tensions de létal et des courants. Évitez le contact avec les surfaces sous tensions.

Avant de faire un travail dans le compteur, assurezvous d'éteindre l'alimentation et de mettre tous les circuits branchés hors tension.

See Section 2.2 for the KYZ output specifications; see Section 7.4 for pulse constants.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-6

5: Communication Installation

Wireless Ethernet Connection

Electronic Circuits

Ia Ia Ib Ib Ic Ic

(+) (-) (+) (-) (+) (-)

Va Vb Vc Vn L1 L2 PE

Z K Y + - SH RS-485

Pulse Contacts

To Other

Devices

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-7

5: Communication Installation

5.1.4: Ethernet Connection

In order to use the Shark® 200S submeter’s Ethernet capability, the Ethernet

Module must be installed in your meter, and the JP2 must be set to positions 2-3. You can use either wired Ethernet, or WiFi.

• For wired Ethernet, use Standard RJ45 10/100BaseT cable to connect to the

Shark® 200S submeter. The RJ45 line is inserted into the RJ45 port of the meter.

• For WiFi connections, make sure you have the correct antenna attached to the meter.

WARNING!

During normal operation of the Shark® 200S meter, dangerous voltages flow through many parts of the meter, including:

Terminals and any connected CTs (Current Transformers) and PTs (Potential

Transformers), all I/O Modules (Inputs and Outputs) and their circuits. All

Primary and Secondary circuits can, at times, produce lethal voltages and currents.

Avoid contact with any current-carrying surfaces.

Before performing ANY work on

the meter, make sure the meter is powered down and all connected circuits

are de-energized.

AVERTISSEMENT!

Pendant le fonctionnement normal du compteur Shark® 200S des tensions dangereuses suivant de nombreuses pièces, notamment, les bornes et tous les transformateurs de courant branchés, les transformateurs de tension, toutes les sorties, les entrées et leurs circuits. Tous les circuits secondaires et primaires peuvent parfois produire des tensions de létal et des courants. Évitez le contact avec les surfaces sous tensions.

Avant de faire un travail dans le compteur, assurezvous d'éteindre l'alimentation et de mettre tous les circuits branchés hors tension.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-8

5: Communication Installation

Wireless Ethernet Connection

Ethernet Module

Electronic Circuits

Ia Ia Ib Ib Ic Ic

(+) (-) (+) (-) (+) (-)

Va Vb Vc Vn L1 L2 PE

Z K Y + - SH

JP2: Must be in position 2-3 for

Ethernet (RJ45 or WiFi)

**

RS-485

To Other

Devices

Refer to Chapter 6 for instructions on how to set up the Network Module.

** See the JP2 figure and instructions on page 5-5.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-9

5: Communication Installation

5.2: Meter Communication and Programming Overview

Programming and communication can utilize the RS485 connection shown in Section

5.1.2 or the RJ45/WiFi connection shown in Section 5.1.4. Once a connection is established, Communicator EXT

TM

software can be used to program the meter and communicate to other devices.

Meter Connection

To provide power to the meter, use one of the wiring diagrams in Chapter 4 or attach an Aux cable to GND, L(+) and N(-).

The RS485 cable attaches to SH, - and + as shown in Section 5.1.2.

5.2.1: How to Connect to the Submeter

1. Open Communicator EXT

TM

software.

2. Click the

Connect

icon on the Icon bar.

The Connect screen opens, showing the Initial settings. Make sure your settings are the same as those shown on the next page, except for the IP Address field, which must be your device’s IP address.The address shown here is the default Ethernet option address.

NOTE:

The settings you make will depend on whether you are connecting to the meter via Serial Port or Network. Use the pull-down menus to make any necessary changes.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-10

5: Communication Installation

Serial Port Connection

Network Connection

3. Click the

Connect

button on the screen.

NOTE:

You may have to disconnect power, reconnect power and then click

Connect

.

The Device Status screen appears, confirming a connection.

4. Click

OK

.

5. Click the

Profile

icon in the Title Bar.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-11

5: Communication Installation

6. You will see the Shark® 200S meter’s Device Profile screen. Use the Tree menu on the left of the screen to navigate between settings screens (see below).

7. Click the

Communications

tab. You will see the screen shown on the next page.

Use this screen to enter communication settings for the meter's two on-board ports: the IrDA port (COM 1) and RS485 port (COM 2) Make any necessary changes to settings.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-12

5: Communication Installation

Valid Communication Settings are as follows:

COM1 (IrDA)

Response Delay (0-750 msec)

COM2 (RS485)

Address (1-247)

Protocol (Modbus RTU, Modbus ASCII or DNP)

Baud Rate (1200 to 57600) Your meter must have Runtime Firmware

Version 26 or higher to set Baud rates of 1200, 2400, and

4800.

Response Delay (0-750 msec)

Parity (Odd, Even, or None) Your meter must have Runtime Firmware

Version 26 or higher to be able to set Parity.

DNP Options for Voltage, Current, and Power - these fields allow you to choose

Primary or Secondary Units for DNP, and to set custom scaling if you choose

Primary. See Chapter 8 in the

Communicator EXT

TM

4.0 and MeterManager EXT

Software User Manual

for more information.

8. When changes are complete, click the

Update Device

button to send a new profile to the meter.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-13

5: Communication Installation

9. Click

Exit

to leave the Device Profile or click other menu items to change other aspects of the Device Profile (see the following section for instructions).

5.2.2: Shark® 200S Meter Device Profile Settings

NOTE:

Only the basic Shark® 200S meter Device Profile settings are explained in this manual. Refer to Chapter 8 in the

Communicator EXT

TM

4.0 and MeterManager EXT

Software User Manual

for detailed instructions on configuring all settings of the meter’s Device Profile. You can view the manual online by clicking

Help>Contents

from the Communicator EXT

TM

Main screen.

CT, PT Ratios and System Hookup

IMPORTANT!

You have two options for entering the CT and PT settings. You can either enter CT/PT Numerator, Denominator, and Multiplier manually (see instructions below), or you can enter the Ratios for CT/PT Numerator and Denominator and click the Update CT/Update PT buttons to let the software calculate the Numerator,

Denominator, and Multiplier for you. You can then empty the Ratio fields and click the

Update Ratio buttons to confirm the calculated settings: you will see the same ratios you initially entered.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-14

5: Communication Installation

For manual entry:

CT Ratios

CT Numerator (Primary): 1 - 9999

CT Denominator (Secondary): 5 or 1 Amp

NOTE

: This field is display only.

Either CT Multiplier (Scaling): 1, 10 or 100

OR Ratio: the ratio to be applied, and click Update CT

Current Full Scale: Display only.

PT Ratios

PT Numerator (Primary): 1 - 9999

PT Denominator (Secondary): 40 - 600

PT Multiplier (Scaling): 1, 10, 100, or 1000

Voltage Full Scale: Display only.

System Wiring

3 Element Wye; 2.5 Element Wye; 2 CT Delta

Example Settings:

For a CT of 2000/5A, set the following CT Ratios in the entry fields:

CT Numerator (Primary) 2000

CT Denominator (Secondary) 5

CT Multiplier 1

The Current Full Scale field will read 2000.

NOTE

: You can obtain the same Current Full Scale by entering a CT Numerator of 200 and a CT Multiplier of 10.

For a system that has 14400V primary with a 120V secondary line to neutral (PT Ratio of 120:1), set the following PT Ratios in the entry fields:

PT Numerator (Primary) 1440

PT Denominator (Secondary) 120

PT Multiplier 10

The Voltage Full Scale field will read 14.4k.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-15

5: Communication Installation

Use the box at the bottom of the screen to enter the minimum voltage threshold, which is a percentage of the voltage full scale. Enter a percentage between 0 and 12.7 in the % entry field. The minimum primary voltage based on the percentage you entered is displayed at the bottom of the screen.

Example CT Settings:

200/5 Amps: Set the Ct-n value for 200, Ct-Multiplier value for 1

800/5 Amps: Set the Ct-n value for 800, Ct-Multiplier value for 1

2,000/5 Amps: Set the Ct-n value for 2000, Ct-Multiplier value for 1

10,000/5 Amps: Set the Ct-n value for 1000, Ct-Multiplier value for 10

Example PT Settings:

277/277 Volts: Pt-n value is 277, Pt-d value is 277, Pt-Multiplier is 1

14,400/120 Volts: Pt-n value is 1440, Pt-d value is 120, Pt-Multiplier value is 10

138,000/69 Volts: Pt-n value is 1380, Pt-d value is 69, Pt-Multiplier value is 100

345,000/115 Volts: Pt-n value is 3450, Pt-d value is 115, Pt-Multiplier value is 100

345,000/69 Volts: Pt-n value is 345, Pt-d value is 69, Pt-Multiplier value is 1000

NOTE:

Settings are the same for Wye and Delta configurations.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-16

5: Communication Installation

Display Configuration

The settings on this screen determine the display configuration of the meter’s faceplate.

The screen fields and acceptable entries are as follows:

Phases Displayed

: A; A and B; A, B, and C. This field determines which phases are displayed on the faceplate. For example, if you select A and B, only those two phases will be displayed on the faceplate.

Auto Scroll Display

: Yes or No. This field enables/disables the scrolling of selected readings on the faceplate. If enabled, the readings scroll every 5 seconds.

Enable on Face Plate of Display

: Check the boxes of the Readings you want displayed on the faceplate of the meter. You must select at least one reading.

Power Direction

: View as Load or View as Generator

Flip Power Factor Sign

: Yes or No

Current (I) Display Autoscale

: On to apply scaling to the current display or Off (No decimal places)

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-17

5: Communication Installation

Display Voltage in Secondary:

Yes or No

Load Bar Custom Configuration:

To enter scaling for the Load Bar, click the Load

Bar Custom Configuration checkbox. Fields display on the screen that allow you to enter a Scaling factor for the display. See the figure below.

Enter the scaling factor you want in the Current Scale field. This field is multiplied by the CT Multiplier (set in the CT, PT Ratios, and System Hookup screen) to arrive at the

Primary Full Scale. Make sure you set the CT multiplier correctly.

Enable Fixed Scale for Voltage Display

: To enter a scaling factor for the Voltage display, click the checkbox next to Enable Fixed Scale for Voltage Display. The screen changes - see the figure below.

Select the scaling you want to use from the pull-down menu. The options are: 0,

100.0kV, 10.00kV, or 0kV.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-18

Energy, Power Scaling, and Averaging

5: Communication Installation

The screen fields and acceptable entries are as follows:

Energy Settings

Energy Digits: 5; 6; 7; 8

Energy Decimal Places: 0 - 6

Energy Scale: unit; kilo (K); Mega (M)

Example: a reading for Digits: 8; Decimals: 3; Scale: K would be formatted as

00123.456k

Power Settings

Power Scale: Auto; unit; kilo (K); Mega (M)

Apparent Power (VA) Calculation Method: Arithmetic Sum; Vector Sum

Demand Averaging

Type: Block or Rolling

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-19

5: Communication Installation

Interval (Block demand) or Sub-Interval (Rolling demand) in minutes: 5; 15; 30; 60

Number of Subintervals: 1; 2; 3; 4

Interval Window: This field is display only. It is the product of the values entered in the Sub-Interval and Number of Subintervals fields.

NOTE:

You will only see the Number of Subintervals and Interval Window fields if you select Rolling Demand.

System Settings

From this screen, you can do the following:

• Enable or disable password for Reset (reset max/min Energy settings, Energy accumulators, and the individual logs) and/or Configuration (Device profile): click the radio button next to Yes or No.

NOTES:

• If you enable a password for reset, you must also enable it for configuration.

• The meter’s default is password disabled.

• Enabling Password protection prevents unauthorized tampering with devices.

When a user attempts to make a change that is under Password protection, the

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-20

5: Communication Installation

Communicator EXT

TM

application opens a screen asking for the password. If the correct password is not entered, the change does not take place.

IMPORTANT!

You must set up a password before enabling Password protection.

Click the

Change

button next to Change Password if you have not already set up a password.

• Change the Password: click the

Change

button. You will see the Enter the New

Password screen, shown below.

1. Type in the new password (0 - 9999).

2. Retype the password.

3. Click

Change

. The new password is saved and the meter restarts.

NOTE:

If Password protection has already been enabled for configuration and you attempt to change the password, you will see the Enter Password screen after you click

Change

. Enter the old password and click

OK

to proceed with the password change.

• Change the Meter Identification: input a new meter label into the Meter Designation field.

Limits

Limits are transition points used to divide acceptable and unacceptable measurements. When a value goes above or below the limit an out-of-limit condition occurs.

Once they are configured, you can view the out-of-Limits (or Alarm) conditions in the

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-21

5: Communication Installation

Limits log or Limits polling screen. You can also use Limits to trigger relays. See the

Communicator EXT

TM

4.0 and MeterManager EXT Software User Manual

for details.

The current settings for Limits are shown in the screen. You can set and configure up to eight Limits for the Shark® 200S meter.

To set up a Limit:

1. Select a Limit by double-clicking on the Assigned Channel field.

2. You will see the screen shown below. Select a Group and an Item for the Limit.

3. Click

OK

.

To configure a Limit:

Double-click on the field to set the following values:

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-22

5: Communication Installation

Above and Below Setpoint

: % of Full Scale (the point at which the reading goes out of limit)

Examples

:

100% of 120V Full Scale = 120V

90% of 120V Full Scale = 108V

Above and Below Return Hysteresis

: the point at which the reading goes back within limit (see figure below)

Examples

:

Above Setpoint = 110%; Below Setpoint = 90%

(Out of Limit above 132V);(Out of Limit below 108V)

Above Return Hysteresis = 105%; Below Return Hysteresis = 95%

(Stay out of Limit until below 126V)(Stay out of Limit until above 114V)

+

MEASURED VALUE

Above Limit condition

Above Limit Trigger point

Return point from Above Limit condition

HYSTERESIS

Return point from Below Limit condition

Below Limit Trigger point

HYSTERESIS

Below Limit condition

0

-

MEASURED VALUE

(if applicable)

TIME

Primary Fields:

These fields are display only. They show what the setpoint and return hysteresis value are for each limit.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-23

5: Communication Installation

NOTES:

• If you are entering negative Limits, be aware that the negative value affects the way the above and below Limits function, since negative numbers are processed as signed values.

• If the Above Return Hysteresis is greater than the Above Setpoint, the Above Limit is Disabled; if the Below Return Hysteresis is less than the Below Setpoint, the

Below Limit is Disabled. You may want to use this feature to disable either Above or

Below Limit conditions for a reading.

IMPORTANT!

When you finish making changes to the Device Profile, click

Update

Device

to send the new Profile settings to the meter.

NOTE:

Refer to Chapter 8 of the

Communicator EXT

TM

4.0 and MeterManager EXT

Software User Manual

for additional instructions on configuring the Shark® 200S meter settings, including Time Setting, Transformer and Line Loss Compensation, CT and PT Compensation, Secondary Voltage display, Symmetrical Components, Voltage and Current Unbalance, and scaling Primary readings for use with DNP.

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 5-24

6: Ethernet Configuration

6: Ethernet Configuration

6.1: Introduction

The Shark® 200S submeter offers an optional WiFi (Wireless) or RJ45 Ethernet connection. This option allows the submeter to be set up for use in a LAN (Local Area

Network), using standard WiFi base stations. Configuration for these connections is easily accomplished through your PC using Telnet connections. Then you can access the submeter to perform meter functions directly through any computer on your LAN: the Shark® 200S meter does not need to be directly connected (wired) to these computers for it to be accessed. This chapter outlines the procedures for setting up the parameters for Ethernet communication.

• Host PC setup - Section 6.2

• Shark® 200S submeter setup - Section 6.3

6.2: Setting up the Host PC to Communicate with Shark® 200S Meter

• Consult with your Network Administrator before performing these steps because some of the functions may be restricted to Administrator privileges.

• The Host PC could have multiple Ethernet Adapters (Network Cards) installed.

Identify and configure the one that will be used for accessing the Shark® 200S meter.

• The PC's Ethernet Adapter must be set up for point-to-point communication when setting up for the Shark® 200S meter. The Factory Default IP parameters programmed in the Shark® 200S meter are:

IP Address: 10.0.0.1

Subnet Mask: 255.255.255.0

See other parameters in Section 6.3.

• The factory default Ethernet mode is WLAN (WiFi) disabled. This means the meter can be accessed via the RJ45 jack and cable connection only!

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 6 - 1

6: Ethernet Configuration

If the settings are lost or unknown in the Shark® 200S meter, follow the procedure in Section 6.4 for restoring Factory Default parameters. Default settings are listed in Section 6.3.

6.2.1: Configuring the Host PC's Ethernet Adapter

The following example shows the PC configuration settings that allow you to access the Shark® 200S meter in default mode. Use the same procedure when the settings are different than the default settings, but are also known to you.

1. From the PC’s Start Menu, select

Control Panel>Network Connections

or

Control Panel>Network and Internet>Network and Sharing Center.

You will see a screen showing your network connections. An example is shown below. Depending on your Operating system, the screen you see may look a bit different.

2. Right click on the Local Area Network connection you will be using to connect to the

Shark® 200S submeter, and select Properties from the pull-down menu. You will see a screen similar to the one shown on the next page.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 6 - 2

6: Ethernet Configuration

3. Select Internet Protocol [TCP/IP] from the middle of the screen and click the

Properties button. You will see the screen shown on the next page.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 6 - 3

6: Ethernet Configuration

4. Click the Use the Following IP Address radio button. The screen changes to allow you to enter the IP Address and Subnet Mask.

a. Enter 10.0.0.2 in the IP Address field.

b. Enter 255.255.255.0 in the Subnet Mask field.

3. Click the

OK

button.

4. You can now close the Local Area Connection Properties and Network Connection windows.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 6 - 4

6: Ethernet Configuration

6.3: Setting up the Ethernet Module in the Shark® 200S Meter

Below are the Factory Default settings for the Shark® 200S meter's Ethernet

Module. These are programmed into the meter before it is shipped out from the factory. Parameters indicated in bold letters (

1, 6, 7

) may need to be altered to satisfy the local Ethernet configuration requirements. Other parameters (2, 3, 4) should not be altered.

Follow the procedure described in Section 6.4 if these Factory Default parameters need to be restored in the meter.

1) Network/IP Settings:

Network Mode.........Wired Only

IP Address..............10.0.0.1

Default Gateway.......--- not set ---

Netmask.................255.255.255.0

2) Serial & Mode Settings:

Protocol.................Modbus/RTU,Slave(s) attached

Serial Interface...... 57600,8,N,1,RS232,CH1

3) Modem/Configurable Pin Settings:

CP0..! Defaults (In) Wired CP1..! GPIO (In) CP2..! GPIO (In)

CP3..! GPIO (In) CP4..! GPIO (In) CP5..! GPIO (In)

CP6..! GPIO (In) CP7..! GPIO (In) CP8..! GPIO (In)

CP9..! GPIO (In) CP10.! GPIO (In)

RTS Output ......... Fixed High/Active

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 6 - 5

6: Ethernet Configuration

4) Advanced Modbus Protocol settings:

Slave Addr/Unit Id Source... Modbus/TCP header

Modbus Serial Broadcasts....Disabled (Id=0 auto-mapped to 1)

MB/TCP Exception Codes.....Yes (return 00AH and 00BH)

Char, Message Timeout........00050msec, 05000msec

6) WLAN Settings:

WLAN............................... Disabled, network:LTRX_IBSS

Topology.......................... Infrastructure, Country: US

Security............................none

TX Data rate.....................11 Mbps auto fallback

Power management..........Disabled

Soft AP Roaming...............N/A

Ad-hoce merging..............Enabled

WLAN Max failed packets..0

7) Security Settings:

SNMP................................Enabled

SNMP Community Name...public

Telnet Setup.....................Enabled

TFTP Download................ Enabled

Port 77FEh....................... Enabled

Enhanced Password..........Disabled

D)efault settings, S)ave, Q)uit without save

Select Command or parameter set (1..7) to change:

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 6 - 6

6: Ethernet Configuration

• The Ethernet Module in the Shark® 200S meter can be locally or remotely configured using a Telnet connection over the network.

• The configuration parameters can be changed at any time and are retained when the meter is not powered up. After the configuration has been changed and saved, the Ethernet module performs a Reset.

• Only one person at a time should be logged into the network port used for setting up the meter. This eliminates the possibility of several people trying to configure the Ethernet interface simultaneously.

6.3.1: Configuring the Ethernet Module in the Shark® 200S Meter

Using Windows XP© on the Host Computer

Establish a Telnet connection to port 9999:

NOTE:

If your PC is running

Windows 7, you need to enable

Telnet before using it.

1. Open the Control Panel.

2. Select Programs and Features.

3. Select Turn Windows features

on or off.

4. Check the box for Telnet Client.

5. Click OK. The Telnet client is

now available.

1. From the Windows Start menu, click

Run

and type 'cmd'.

2. Click the

OK

button to bring up Windows's Command Prompt window.

3. In the Command Prompt window, type:

telnet 10.0.0.1 9999

and press the

Enter

key.

NOTE:

Be sure to include a space between the IP address and 9999.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 6 - 7

6: Ethernet Configuration

When the Telnet connection is established you will see a message similar to the example shown below.

4. To proceed to Setup Mode press

Enter

again. You will see a screen similar to the one shown below.

5. Type the number for the group of parameters you need to modify. After the group is selected, the individual parameters display for editing. Either:

• Enter a new parameter if a change is required.

• Press Enter to proceed to the next parameter without changing the current one.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 6 - 8

6: Ethernet Configuration

Change Settings 1, 6, and 7 ONLY! Settings 2, 3, and 4 MUST have the default values shown above.

6. Continue setting up parameters as needed. After finishing your modifications, make sure to press the "S" key on the keyboard. This will save the new values and perform a Reset in the Ethernet Module.

6.3.2: Example of Modifying Parameters in Groups 1, 6, and 7

Follow the steps in 6.3.1 to enter Setup Mode.

Network IP Settings Detail (1) (Set device with static IP Address.)

Network Mode: 0=Wired only, 1=Wireless Only <0> ? Key 1 and press Enter for WiFi mode.

IP Address <010> 192.<000> 168.<000> .<000> .<001> You can change the IP address in this setting.

Set Gateway IP Address <N> ? Y (If you want to change the Gateway address.)

Gateway IP Address : <192> .<168> .<000> .<001> (You can change the Gateway address in this setting.)

Set Netmask <N for default> <Y> ? Y (If you want to change the Netmask.)

<255> .<255> .<255> .<000> (You can change the Netmask in this setting.)

Change telnet config password <N> ? N

WLAN Settings Detail (6)

(The settings shown are recommended by EIG for use with the Shark® 200S meter. You will only be able to access these settings if you have set Network Mode to “1” (to select Wireless mode) in the Network IP Settings

Detail, shown previously.)

Topology: 0=Infrastructure, 1=Ad-Hoc <1> ? 0

Network Name: EIG_SHARKS

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 6 - 9

6: Ethernet Configuration

Security suite: 0=none, 1=WEP, 2=WPA, 3=WPA2/802.11i <0> ? Enter the number

of the encryption method are using, e.g., 3 for WPA2/802.11i.

If you select “1” (WEP), you will see the following settings:

Authentication 0=open/none, 1=shared <0> ? (Enter 1 if you want the encryption key matched with a communication partner before messages are passed through.)

Encryption 1=WEP64, 2=WEP128 <1> 2

Change Key <N> Y

Display Key <N> N

Key Type 0=hex, 1=passphrase <0> 0

Enter Key:

You can manually enter 26 hexadecimal characters (required for 128-bit encryption) or you can use a WEP Key provider online (for example: www.powerdog.com/wepkey.cgi). WEP Key providers should note on their website that their encryption algorithm is for the Wired Equivalent Privacy portion of IEEE

802.11b/g.

WEP Key Provider Steps

1. Input 26 alphanumeric characters as your Passphrase.

IMPORTANT!

Remember your Passphrase.

PASSPHRASE TO HEXADECIMAL WEP KEYS

Enter the passphrase below.

1009egbck001036ab

Generate keys

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 6 - 10

6: Ethernet Configuration

2. Click the Generate Keys button. Your Hexadecimal WEP Keys display.

PASSPHRASE TO HEXADECIMAL WEP KEYS

The passphrase 1009egbcke001306ab produces the following keys:

64-BIT (40-BIT KEYS)

1.

AA43FB768D

2.

637D8DB9CE

3.

AFDE50AF61

4.

0c35E73E25

128-BIT (104-BIT) KEY

041D7773D8B2C1D97BE9531DC

3. Enter the 128-bit Key.

TX Key Index <1> ? 1 (The WEP key used for transmissions - must be a value between 1 and 4.)

TX Data Rate: 0=fixed, 1=auto fallback <1> ? 1

TX Data rate: 0=1, 1=2, 2=5.5, 3=11, 4=18, 5=24, 6=36, 7=54 Mbps <7> ?

Enter data transmission rate, e.g., 7 for 54Mbps.

Minimum Tx Data rate: 0=1, 1=2, 2=5.5, 3=11, 4=18, 5=24, 6=36,

7=54 Mbps <0> ? 0

Enable Power management <N> ? Y

Enable Soft AP Roaming <N> ? N

Max Failed Packets (6-64, 255=disable) <6>? 6

If you select “2” (WPA), you will make the following settings:

Change Key <N> Y

Display Key <N> N

Key Type 0=hex, 1=passphrase <0> 1

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 6 - 11

6: Ethernet Configuration

Enter Key: (The maximum length of the passphrase is 63 characters. EIG recommends using a passphrase of 20 characters or more for maximum security.)

Encryption: 0=TKIP, 1=TKIP+WEP <0> ? Set the type to the minimum required security level. The “+” sign indicates that the group (broadcast) encryption method is different from the pairwise (unicast) encryption (WEP and TKIP).

TX Data rate: 0=fixed, 1=auto fallback <1> ? 1

TX Data rate: 0=1, 1=2, 2=5.5, 3=11, 4=18, 5=24, 6=36, 7=54 Mbps <7> ?

Enter data transmission rate, e.g., 7 for 54Mbps.

Minimum Tx Data rate: 0=1, 1=2, 2=5.5, 3=11, 4=18, 5=24, 6=36,

7=54 Mbps <0> ? 0

Enable Power management <N> ? Y

Enable Soft AP Roaming <N> ? N

Max Failed Packets (6-64, 255=disable) <6>? 6

If you select “3” (WPA2/802.11i), you will make the following settings:

Change Key <N> Y

Display Key <N> N

Key Type 0=hex, 1=passphrase <0> 1

Enter Key: (The maximum length of the passphrase is 63 characters. EIG recommends using a passphrase of 20 characters or more for maximum security.)

Encryption: 0=CCMP, 1=CCMP+TKIP, 2=CCMP+WEP, 3=TKIP, 4=TKIP+WEP

<3> ? (Set the type to the minimum required security level. The “+” sign indicates that the group (broadcast) encryption method is different from the pair-

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 6 - 12

6: Ethernet Configuration wise (unicast) encryption. For example, for CCMP+TKIP, CCMP is the pairwise encryption and TKIP is the group encryption. CCMP is the default for WPA2.)

TX Data rate: 0=fixed, 1=auto fallback <1> ? 1

TX Data rate: 0=1, 1=2, 2=5.5, 3=11, 4=18, 5=24, 6=36, 7=54 Mbps <7> ?

Enter data transmission rate, e.g., 7 for 54Mbps.

Minimum Tx Data rate: 0=1, 1=2, 2=5.5, 3=11, 4=18, 5=24, 6=36,

7=54 Mbps <0> ? 0

Enable Power management <N> ? Y

Enable Soft AP Roaming <N> ? N

Max Failed Packets (6-64, 255=disable) <6>? 6

Security Settings (7)

Disable SNMP <N> ? N

SNMP Community Name <public>: (You can enter an SNMP community name here.)

Disable Telnet Setup <N> ? N (If you change this setting to Y, you will not be able to use Telnet to re-configure the Network card once you save the settings, without resetting the Network card, as shown in Section 6.4. However, you may want to disable

Telnet setup and Port 77FEh to prevent users from accessing the setup from the network.)

Disable TFTP Firmware Update <N> ? N

Disable Port 77FEh <N> ? N (For security purposes, you may want to disable Telnet setup and Port 77FEh to prevent users from accessing the setup from the network.)

Enable Enhanced Password <N> ? N

Exiting the screen

CAUTION!

DO NOT PRESS 'D': that will restore the Default Settings.

Press 'S' to Save the settings you've entered.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 6 - 13

6: Ethernet Configuration

6.4: Network Module Hardware Initialization

If you don't know your current Network Module settings, or if the settings are lost, you can use this method to initialize the hardware with known settings you can then work with.

Main Board

Reset

Button

JP3

JP2

WARNING!

During normal operation of the Shark® 200S meter, dangerous voltages flow through many parts of the meter, including:

Terminals and any connected CTs (Current Transformers) and PTs

(Potential Transformers), all I/O Modules (Inputs and Outputs) and their

circuits. All Primary and Secondary circuits can, at times, produce lethal voltages and

currents. Avoid contact with any current-carrying surfaces.

Before performing ANY

work on the meter, make sure the meter is powered down and all connected

circuits are de-energized.

AVERTISSEMENT!

Pendant le fonctionnement normal du compteur Shark® 200S des tensions dangereuses suivant de nombreuses pièces, notamment, les bornes et

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 6 - 14

6: Ethernet Configuration tous les transformateurs de courant branchés, les transformateurs de tension, toutes les sorties, les entrées et leurs circuits. Tous les circuits secondaires et primaires peuvent parfois produire des tensions de létal et des courants. Évitez le contact avec les surfaces sous tensions.

Avant de faire un travail dans le compteur, assurezvous d'éteindre l'alimentation et de mettre tous les circuits branchés hors tension.

1. Place a shorting block on JP3 and press the

Reset

button on the main board.

NOTE:

JP3 is located on the right hand side, upper corner of the main board. The shorting block can be "borrowed" from JP2, located at the middle, right hand side.

See the figure shown on the previous page.

2. After you press the

Reset

button, move the jumper back to JP2.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 6 - 15

6: Ethernet Configuration

This page intentionally left blank.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 6 - 16

7: Using the Submeter

7: Using the Submeter

7.1: Introduction

The Shark® 200S submeter can be configured and a variety of functions can be accomplished by using the Elements and the Buttons on the submeter face. This chapter reviews front panel navigation. See Appendix A for complete Navigation maps.

7.1.1: Understanding Submeter Face Elements

Reading

Type

Indicator

IrDA Com

Port

% of Load

Bar

LM1

LM2

%THD

PRG

MIN

MAX

IrDA

120%-

90%-

60%-

30%-

%LOAD

MENU

ENTER

120

.

0

120

.

0

120

.

0

A

VOLTS L-N

VOLTS L-N

AMPS

W/VAR/PF

B

VA/Hz

Wh

VARh

VAh

C

Wh Pulse

KILO

MEGA

Parameter

Designator

Watt-hour

Test Pulse

Scaling

Factor

Figure 7.1: Faceplate with Elements

The meter face features the following elements:

• Reading Type Indicator: e.g., Max

• Parameter Designator: e.g., Volts L-N

• Watt-Hour Test Pulse: Energy pulse output to test accuracy

• Scaling Factor: Kilo or Mega multiplier of displayed readings

• % of Load Bar: Graphic Display of Amps as % of the Load (Refer to Section 7.3 for additional information.)

• IrDA Communication Port: Com 1 port for wireless communication

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 7-1

7: Using the Submeter

7.1.2: Understanding Submeter Face Buttons

MIN

LM1

LM2

%THD

PRG

IrDA

120%-

90%-

60%-

%LOAD

MENU ENTER

120

.

0

120

.

0

120

.

0

A

VOLTS L-N

VOLTS L-N

AMPS

W/VAR/PF

VA/Hz

B

Wh

VARh

VAh

C

Wh Pulse

KILO

MEGA

Figure 7.2: Faceplate with Buttons

The meter face has

Menu

,

Enter

,

Down

and

Right

buttons, which let you perform the following functions:

• View Meter Information

• Enter Display Modes

• Configure Parameters (may be Password Protected)

• Perform Resets (may be Password Protected)

• Perform LED Checks

• Change Settings

• View Parameter Values

• Scroll Parameter Values

• View Limit States

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 7-2

7: Using the Submeter

7.2: Using the Front Panel

You can access four modes using the Shark® 200S submeter’s front panel buttons:

• Operating mode (Default)

• Reset mode

• Configuration mode

• Information mode - Information mode displays a sequence of screens that show model information, such as Frequency, Amps, V-Switch, etc.

Use the

Menu

,

Enter

,

Down

and

Right

buttons to navigate through each mode and its related screens.

NOTES:

• See Appendix A for the complete display mode Navigation maps.

• The meter can also be configured using software; see Chapter 5 and the

Communicator EXT

TM

4.0 and MeterManager EXT Software User Manual

for instructions.

7.2.1: Understanding Startup and Default Displays

Upon Power Up, the meter displays a sequence of screens:

• Lamp Test screen where all LEDs are lit

• Lamp Test screen where all digits are lit

• Firmware screen showing build number

• Error screen (if an error exists)

After startup, if auto-scrolling is enabled, the Shark® 200S meter scrolls the parameter readings on the right side of the front panel. The Kilo or Mega LED lights, showing the scale for the Wh, VARh and VAh readings. Figure 7.3 shows an example of a Wh reading.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 7-3

7: Using the Submeter

IrDA

120%-

LM1

LM2

MIN

MAX

%THD

PRG

90%-

60%-

30%-

%LOAD

MENU ENTER

0000

0.659

A

VOLTS L-N

VOLTS L-N

AMPS

W/VAR/PF

VA/Hz

Wh

B

VARh

VAh

C

Wh Pulse

KILO

MEGA

Figure 7.3: Display Showing Watt-hr Reading

The Shark® 200S meter continues to provide scrolling readings until one of the buttons on the front panel is pressed, causing the meter to enter one of the other

Modes.

7.2.2: Using the Main Menu

1. Press the

Menu

button. The Main Menu screen appears.

• The Reset: Demand mode (rStd) appears in the A window. Use the Down button to scroll, causing the Reset: Energy (rStE), Configuration (CFG), Operating (OPr), and

Information (InFo) modes to move to the A window.

• The mode that is currently flashing in the A window is the “Active” mode, which means it is the mode that can be configured.

MENU ENTER MENU ENTER

MENU ENTER

-

A

-

A

-

A

-

B

-

B

-

B

-

C

-

C

-

C

For example: Press Down Twice - CFG moves to A window. Press Down Twice- OPr moves to A window.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 7-4

7: Using the Submeter

2. Press the

Enter

button from the Main Menu to view the Parameters screen for the mode that is currently active.

7.2.3: Using Reset Mode

Reset Mode has two options:

• Reset: Demand (rStd): resets the Max and Min values

• Reset: Energy (rStE): resets the energy accumulator fields

1. Press the Enter button while either rStd or rStE is in the A window. The Reset

Demand No or Reset Energy No screen appears.

-

-

• If you press the

Enter

button again, the Main Menu appears, with the next mode in the A window. (The

Down

button does not affect this screen.)

-

MENU ENTER

A

B

C

-

-

-

MENU ENTER

A

B

C

MENU ENTER

MENU ENTER

• If you press the

Right

button, the

Reset Demand YES or Reset Energy

YES screen appears. Press

Enter

to perform a reset.

-

-

A

B

-

-

A

B

-

C

-

C

NOTE:

If Password protection is enabled for reset, you must enter the four digit password before you can reset the meter. (See Chapter 5 for information on Password protection.) To enter a password, follow the instructions in Section 7.2.4.

CAUTION!

Reset Demand YES resets

all

Max and Min values.

2. Once you have performed a reset, the screen displays either “rSt dMd donE” or

“rSt EnEr donE”and then resumes auto-scrolling parameters.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 7-5

7: Using the Submeter

7.2.4: Entering a Password

If Password protection has been enabled in the software for reset and/or configuration

(see Chapter 5 for more information), a screen appears requesting a password when you try to reset the meter and/or configure settings through the front panel.

• PASS appears in the A window and 4 dashes appear in the B window. The leftmost dash is flashing.

1. Press the

Down

button to scroll numbers from 0 to 9 for the flashing dash. When the correct number appears for that dash, use the

Right

button to move to the next dash.

Example

: The left screen, below, shows four dashes. The right screen shows the display after the first two digits of the password have been entered.

-

-

MENU ENTER

A

B

-

-

MENU ENTER

PASS

12__

A

B

-

C

-

C

2. When all 4 digits of the password have been selected, press the

Enter

button.

• If you are in Reset Mode and you enter the correct password, “rSt dMd donE” or

“rSt EnEr donE” appears and the screen resumes auto-scrolling parameters.

• If you are in Configuration Mode and you enter the correct password, the display returns to the screen that required a password.

• If you enter an incorrect password, “PASS ---- FAIL” appears and:

• The previous screen is re-displayed, if you are in

Reset Mode.

• The previous Operating mode screen is re-displayed, if you are in Configuration mode.

-

-

-

MENU ENTER

A

B

C

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 7-6

7: Using the Submeter

7.2.5: Using Configuration Mode

Configuration mode follows Reset: Energy on the Main Menu.

To access Configuration mode

1. Press the

Menu

button while the meter is auto-scrolling parameters.

2. Press the

Down

button until the Configuration Mode option (CFG) is in the A window.

3. Press the

Enter

button. The Configuration Parameters screen appears.

4. Press the

Down

button to scroll through the configuration parameters: Scroll

(SCrL), CT, PT, Connection (Cnct) and Port. The parameter currently ‘Active,” i.e., configurable, flashes in the A window.

5. Press the

Enter

button to access the Setting screen for the currently active parameter.

NOTE:

You can use the

Enter

button to scroll through all of the Configuration parameters and their Setting screens, in order.

-

-

-

MENU ENTER

A

B

C

-

-

-

MENU ENTER

A

B

C

Press

Enter

when CFG is in A window - Parameter screen appears -

Press

Down

- Press

Enter

when

Parameter you want is in A window

6. The parameter screen appears, showing the current settings. To change the settings:

• Use either the

Down

button or the

Right

button to select an option.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 7-7

7: Using the Submeter

• To enter a number value, use the

Down

button to select the number value for a digit and the

Right

button to move to the next digit.

NOTE:

When you try to change the current setting and Password protection is enabled for the meter, the Password screen appears. See Section 7.2.4 for instructions on entering a password.

7. Once you have entered the new setting, press the

Menu

button twice.

8. The Store ALL YES screen appears. You can either:

• Press the

Enter

button to save the new setting.

• Press the

Right

button to access the Store ALL no screen; then press the

Enter

button to cancel the Save.

9. If you have saved the settings, the Store ALL done screen appears and the meter resets.

MENU ENTER MENU ENTER

MENU ENTER

-

-

-

A

B

C

-

-

-

A

B

C

-

-

-

A

B

C

Press the

Enter

button to save Press the

Enter

button to The settings have been the settings. Press the

Right

Cancel the Save. saved.

button for Stor All no screen.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 7-8

7: Using the Submeter

7.2.5.1: Configuring the Scroll Feature

When in Auto Scroll mode, the meter performs a scrolling display, showing each parameter for 7 seconds, with a 1 second pause between parameters. The parameters that the meter displays have been selected through software (refer to the

Communicator EXT

TM

4.0 and MeterManager EXT Software User Manual

for instructions).

To enable or disable Auto-scrolling:

1. Press the

Enter

button when SCrl is in the A window. The Scroll YES screen appears.

2. Press either the

Right

or

Down

button if you want to access the Scroll no screen. To return to the Scroll YES screen, press either button.

-

3. Press the

Enter

button on either the Scroll YES screen (to enable auto-scrolling) or the Scroll no screen (to disable auto-scrolling).

-

-

MENU ENTER

4. The CT- n screen appears (this is the next Configuration mode parameter).

-

NOTES:

-

• To exit the screen without changing scrolling options, press the

Menu

button.

-

MENU ENTER

A

B

C

A

B

C

• To return to the Main Menu screen, press the

Menu

button twice.

• To return to the scrolling (or non-scrolling) parameters display, press the

Menu

button three times.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 7-9

7: Using the Submeter

7.2.5.2: Configuring CT Setting

The CT Setting has three parts: Ct-n (numerator), Ct-d (denominator), and Ct-S

(scaling).

1. Press the

Enter

button when Ct is in the A window. The Ct-n screen appears. You can either:

• Change the value for the CT numerator.

• Access one of the other CT screens by pressing the

Enter

button: press

Enter

once to access the Ct-d screen, twice to access the Ct-S screen.

NOTE:

The Ct-d screen is preset to a 5 Amp or 1 Amp value at the factory and cannot be changed.

a. To change the value for the CT numerator:

From the Ct-n screen:

• Use the Down button to select the number value for a digit.

• Use the Right button to move to the next digit.

b. To change the value for CT scaling

From the Ct-S screen:

Use the

Right

button or the

Down

button to choose the scaling you want. The

Ct-S setting can be 1, 10, or 100.

NOTE:

If you are prompted to enter a password, refer to Section 7.2.4 for instructions on doing so.

2. When the new setting is entered, press the

Menu

button twice.

3. The Store ALL YES screen appears. Press

Enter

to save the new CT setting.

Example CT Settings

:

200/5 Amps: Set the Ct-n value for 200 and the Ct-S value for 1.

800/5 Amps: Set the Ct-n value for 800 and the Ct-S value for 1.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 7-10

7: Using the Submeter

2,000/5 Amps: Set the Ct-n value for 2000 and the Ct-S value for 1.

10,000/5 Amps: Set the Ct-n value for 1000 and the Ct-S value for 10.

NOTES:

• The value for Amps is a product of the Ct-n value and the Ct-S value.

• Ct-n and Ct-S are dictated by primary current; Ct-d is secondary current.

-

-

-

MENU ENTER

A

B

C

-

-

-

MENU ENTER

A

B

C

-

-

-

MENU ENTER

A

-

B

-

C

-

MENU ENTER

A

B

C

Press

Enter

Use buttons to set Ct-n Ct-d cannot be changed Use buttons to select

scaling

7.2.5.3: Configuring PT Setting

The PT Setting has three parts: Pt-n (numerator), Pt-d (denominator), and Pt-S (scaling).

1. Press the

Enter

button when Pt is in the A window. The PT-n screen appears. You can either:

• Change the value for the PT numerator.

• Access one of the other PT screens by pressing the

Enter

button: press

Enter

once to access the Pt-d screen, twice to access the Pt-S screen.

a. To change the value for the PT numerator or denominator:

From the Pt-n or Pt-d screen:

• Use the

Down

button to select the number value for a digit.

• Use the

Right

button to move to the next digit.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 7-11

7: Using the Submeter

-

-

-

b. To change the value for the PT scaling:

From the Pt-S screen:

Use the

Right

button or the

Down

button to choose the scaling you want. The

Pt-S setting can be 1, 10, 100, or 1000.

NOTE:

If you are prompted to enter a password, refer to Section 7.2.4 for instructions on doing so.

2. When the new setting is entered, press the

Menu

button twice.

3. The STOR ALL YES screen appears. Press

Enter

to save the new PT setting.

Example PT Settings

:

277/277 Volts: Pt-n value is 277, Pt-d value is 277, Pt-S value is 1.

14,400/120 Volts: Pt-n value is 1440, Pt-d value is 120, Pt-S value is 10.

138,000/69 Volts: Pt-n value is 1380, Pt-d value is 69, Pt-S value is 100.

345,000/115 Volts: Pt-n value is 3450, Pt-d value is 115, Pt-S value is 100.

345,000/69 Volts: Pt-n value is 345, Pt-d value is 69, Pt-S value is 1000.

NOTE:

Pt-n and Pt-S are dictated by primary voltage; Pt-d is secondary voltage.

MENU ENTER MENU ENTER MENU ENTER

A

B

C

-

-

-

A

B

C

-

-

-

A

B

C

Use buttons to set Pt-n Use buttons to set Pt-d Use buttons to select scaling

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 7-12

7: Using the Submeter

7.2.5.4: Configuring Connection Setting

1. Press the

Enter

button when Cnct is in the A window. The Cnct screen appears.

2. Press the

Right

button or

Down

button to select a configuration. The choices are:

• 3 Element Wye (3 EL WYE)

• 2.5 Element Wye (2.5EL WYE)

• 2 CT Delta (2 Ct dEL)

NOTE:

If you are prompted to enter a password, refer to Section 7.2.4 for instructions on doing so.

3. When you have made your selection, press the

Menu

button twice.

4. The STOR ALL YES screen appears. Press

Enter

to save the setting.

MENU ENTER

-

-

A

B

-

C

Use buttons to select configuration

7.2.5.5: Configuring Communication Port Setting

Port configuration consists of: Address (a three digit number), Baud Rate (9600;

19200; 38400; or 57600), and Protocol (DNP 3.0; Modbus RTU; or Modbus ASCII).

1. Press the

Enter

button when POrt is in the A window. The Adr (address) screen appears. You can either:

• Enter the address.

• Access one of the other Port screens by pressing the

Enter

button: press

Enter

once to access the bAUd screen (Baud Rate), twice to access the Prot screen

(Protocol).

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 7-13

7: Using the Submeter a. To enter the Address

From the Adr screen:

• Use the

Down

button to select the number value for a digit.

• Use the

Right

button to move to the next digit.

b. To select the Baud Rate:

From the bAUd screen:

Use the

Right

button or the

Down

button to select the setting you want.

c. To select the Protocol:

From the Prot screen:

Press the

Right

button or the

Down

button to select the setting you want.

NOTE:

If you are prompted to enter a password, refer to Section 7.2.4 for instructions on doing so.

2. When you have finished making your selections, press the

Menu

button twice.

3. The STOR ALL YES screen appears. Press

Enter

to save the settings.

-

-

-

MENU ENTER

A

B

C

-

-

-

MENU ENTER

A

B

C

-

-

-

MENU ENTER

A

B

C

Use buttons to enter Address Use buttons to select Baud Rate Use buttons to select Protocol

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 7-14

7: Using the Submeter

7.2.6: Using Operating Mode

Operating mode is the Shark® 200S submeter’s default mode, that is, the standard front panel display. After starting up, the meter automatically scrolls through the parameter screens, if scrolling is enabled. Each parameter is shown for 7 seconds, with a 1 second pause between parameters. Scrolling is suspended for 3 minutes after any button is pressed.

1. Press the

Down

button to scroll all the parameters in Operating mode. The currently “Active,” i.e., displayed, parameter has the Indicator light next to it, on the right face of the meter.

2. Press the

Right

button to view additional readings for that parameter. The table below shows possible readings for Operating mode. Sheet 2 in Appendix A shows the Operating mode Navigation map.

VOLTS L-N

VOLTS L-L

AMPS

W/VAR/PF

VA/Hz

Wh

NOTE:

Readings or groups of readings are skipped if not applicable to the meter type or hookup, or if they are disabled in the programmable settings.

OPERATING MODE PARAMETER READINGS

VARh

VAh

POSSIBLE READINGS

VOLTS_LN

VOLTS_LL

VOLTS_L-

N_MAX

VOLTS_LL_

MAX

AMPS

W_VAR_PF W_VAR_P-

F_MAX_-

POS

VA_FREQ

AMPS_-

NEUTRAL

VA_FREQ_-

MAX

KWH_DEL KWH_REC

KVARH_-

POS

KVAH

KVAR-

H_NEG

VOLTS_L-

N_MIN

VOLTS_LL_

MIN

VOLTS_L-

N_THD

AMPS_MAX AMPS_MIN AMPS_THD

W_VAR_P-

F_MIN_POS

VA_FRE-

Q_MIN

KWH_NET

KVAR-

H_NET

W_VAR_P-

F_MIN_NE

G

KWH_TOT

KVARH_-

TOT

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 7-15

7: Using the Submeter

7.3: Understanding the % of Load Bar

The 10-segment LED bar graph at the bottom left of the Shark® 200S meter’s front panel provides a graphic representation of Amps. The segments light according to the load, as shown in the table below.

When the Load is over 120% of Full Load, all segments flash “On” (1.5 secs) and “Off”

(0.5 secs).

Segments Load >= % Full Load none

1-5

1-6

1-7

1-8

1

1-2

1-3

1-4

1-9

1-10

All Blink

1%

15%

30%

45%

60%

72%

84%

96%

108%

120%

>120%

no load

10

1

LM1

LM2

MIN

MAX

%THD

PRG

IrDA

120%-

90%-

60%-

30%-

%LOAD

MENU ENTER

120

.

0

120

.

0

120

.

0

C

A

VOLTS L-N

VOLTS L-N

AMPS

W/VAR/PF

VA/Hz

Wh

B

VARh

VAh

Wh Pulse

KILO

MEGA

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 7-16

7: Using the Submeter

7.4: Performing Watt-Hour Accuracy Testing (Verification)

To be certified for revenue metering, power providers and utility companies must verify that the billing energy meter performs 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 Shark® 200S submeter 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.

• Refer to Figure 7.5 for an example of how this process works.

• Refer to Table 7.1 for the Wh/Pulse constants for accuracy testing.

IrDA

120%-

LM1

LM2

%THD

PRG

MIN

MAX

90%-

60%-

30%-

%LOAD

MENU ENTER

0000

0.659

A

B

VOLTS L-N

VOLTS L-N

AMPS

W/VAR/PF

VA/Hz

Wh

VARh

VAh

C

Wh Pulse

KILO

MEGA

Watt-hour

Test Pulse

Figure 7.4: Watt-hour Test Pulse

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 7-17

7: Using the Submeter

%THD

LM2

LM1

MAX

MIN

-

PRG

-

lrDA

120%-

90%-

-

60%-

30%-

%LOAD

MENU ENTER

A

B

VOLTS L-N

VOLTS L-L

AMPS

WNARP

VA/Hz

Wh

VARh

VAh

C

Wh Pulse

KILO

MEGA

Test Pulses

Comparator

Energy Pulses

Energy

Standard

Error

Results

Figure 7.5: Using the Watt-hour Test Pulse

Input Voltage Level Class 10 Models Class 2 Models

Below 150V 0.500017776

0.1000035555

Above 150V 2.000071103

0.400014221

Table 7.1: Infrared & KYZ Pulse Constants for Accuracy Testing - Kh Watt-hour per pulse

NOTES:

• Minimum pulse width is 90 milliseconds.

• Refer to Chapter 2, Section 2.2, for Wh Pulse specifications.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 7-18

A: Shark® 200-S Meter Navigation Maps

A: Shark® 200S Meter Navigation Maps

A.1: Introduction

You can configure the Shark® 200S meter and perform related tasks using the buttons on the meter face. Chapter 7 contains a description of the buttons on the meter face and instructions for programming the meter using them. The meter can also be programmed using software (see Chapter 5 and the

Communicator EXT

TM

4.0 and MeterManager EXT Software User Manual

).

A.2: Navigation Maps (Sheets 1 to 4)

The Shark® 200S meter’s Navigation maps begin on the next page. The maps show in detail how to move from one screen to another and from one display mode to another using the buttons on the face of the meter. All display modes automatically return to Operating mode after 10 minutes with no user activity.

Shark® 200S meter Navigation map titles

• Main Menu Screens (Sheet 1)

• Operating mode screens (Sheet 2)

• Reset mode screens (Sheet 3)

• Configuration mode screens (Sheet 4)

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 A-1

A: Shark® 200-S Meter Navigation Maps

Main Menu Screens (Sheet 1)

STARTUP

sequence run once at meter startup:

2 lamp test screens, hardware information screen, firmware version screen,

(conditional) error screens

MAIN MENU:

OPR (blinking)

RSTD

RSTE

DOWN

MAIN MENU:

RSTD (blinking)

RSTE

CFG

DOWN sequence completed

DOWN

MAIN MENU:

RSTE (blinking)

CFG

INFO

DOWN

MAIN MENU:

CFG (blinking)

INFO

OPR

DOWN

MAIN MENU:

INFO (blinking)

OPR

RSTD

10 minutes with no user activity sequence completed

MENU

ENTER

OPERATING MODE

grid of meter data screens.

See pages A-3

ENTER

MENU

RESET DEMAND MODE

sequence of screens to get password, if required, and reset max/min data.

See page A-4

ENTER

MENU

MENU

RESET ENERGY MODE

sequence of screens to get password, if required, and reset energy accumulators.

See page A-4

ENTER

CONFIGURATION MODE

grid of meter settings screens with password-protected edit capability.

See page A-5

MENU

ENTER

INFORMATION

sequence of screens to show model information, same as STARTUP except lamp tests omitted.

10 minutes with no user activity

Configuration Mode is not available during a

Programmable Settings update via a COM port.

SYMBOLS

single screen all screens for a display mode group of screens action taken button

MAIN MENU Screen

MAIN MENU screen scrolls through 4 choices, showing 3 at a time. The top choice is always the

"active" one, which is indicated by blinking the legend.

MENU

BUTTONS

Returns to previous menu from any screen in any mode

ENTER Indicates acceptance of the current screen and advances to the next one

DOWN, RIGHT

Navigation:

Editing:

Navigation and edit buttons

No digits or legends are blinking. On a menu, down advances to the next menu selection, right does nothing. In a grid of screens, down advances to the next row, right advances to the next column. Rows, columns, and menus all navigate circularly.

A digit or legend is blinking to indicate that it is eligible for change. When a digit is blinking, down increases the digit value, right moves to the next digit. When a legend is blinking, either button advances to the next choice legend.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 A-2

A: Shark® 200-S Meter Navigation Maps

Operating Mode Screens (Sheet 2)

VOLTS_LN

See Notes 1 & 3

RIGHT

RIGHT

VOLTS_LN_MAX

RIGHT

VOLTS_LN_MIN

DOWN 2

(from any VOLTS_LN

screen)

VOLTS_LL

DOWN

2

RIGHT

RIGHT

VOLTS_LL_MAX

RIGHT

See Note 1

VOLTS_LL_MIN

DOWN

2

(from any VOLTS_LL screen)

AMPS

RIGHT

IN

RIGHT

RIGHT

AMPS_MAX

RIGHT

See Note 1

AMPS_MIN

DOWN 2

DOWN

2

(from any AMPS screen)

W_VAR_PF

RIGHT

W_VAR_PF

_MAX_POS

RIGHT

RIGHT

W_VAR_PF

_MIN_POS

RIGHT

W_VAR_PF

_MAX_NEG

RIGHT

See Note 1

W_VAR_PF

_MIN_NEG

DOWN

2

DOWN

2

(from any W_VAR_PF screen)

VA_FREQ

RIGHT

RIGHT

VA_FREQ_MAX

RIGHT

See Note 1

VA_FREQ_MIN

DOWN

2

(from any VA_FREQ screen)

KWH_REC

RIGHT

KWH_DEL

RIGHT

RIGHT

KWH_NET

RIGHT

See Note 1

KWH_TOT

DOWN

2

(from any KWH screen)

KVARH_POS

RIGHT

KVARH_NEG

RIGHT

RIGHT

KVARH_NET

RIGHT

See Note 1

KVARH_TOT

DOWN

2

(from any KVARH screen)

See Note 1

KVAH

Notes

1 Group is skipped if not applicable to the meter type or hookup or if explicitly disabled via programmable settings.

2 DOWN occurs without user intervention every 7 seconds if scrolling is enabled.

3 No Volts LN screens for Delta 2CT hookup.

4 Scrolling is suspended for 3 minutes after any button press.

MENU

(from any operating mode screen) to Main Menu see page A-2

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 A-3

A: Shark® 200-S Meter Navigation Maps

Reset Mode Screens (Sheet 3)

from MAIN MENU

(RSTD selected) from MAIN MENU

(RSTE selected)

ENTER

ENTER

RESET_MM_NO:

RST

DMD no (blinking)

RIGHT RIGHT

RESET_MM_YES:

RST

DMD yes (blinking)

ENTER is password required?

no reset all max & min values demand

RESET_ENERGY_NO:

RST

ENER no (blinking)

RIGHT RIGHT

RESET_ENERGY_YES:

RST

ENER yes (blinking)

ENTER is password required?

no reset all max & min values demand energy increment blinking digit yes yes

DOWN

RESET_ENTER_PW:

PASS

#### (one # blinking)

RIGHT make next digit blink

ENTER is password correct?

energy yes which reset?

no which reset?

2 sec

RESET_PW_FAIL:

PASS

####

FAIL

RESET_MM_CONFIRM:

RST

DMD

DONE

2 sec.

to previous operating mode screen see page A-3

RESET_ENERGY_CONFIRM:

RST

ENER

DONE

2 sec.

to previous operating mode screen see page A--3 or this page, above

MENU

(from any reset mode screen) to Main Menu see page A-2

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 A-4

A: Shark® 200-S Meter Navigation Maps

Configuration Mode Screens (Sheet 4)

See Note 1

CONFIG_MENU:

SCRL (blinking)

CT

PT

DOWN

CONFIG_MENU:

CT (blinking)

PT

CNCT

DOWN

CONFIG_MENU:

PT (blinking)

CNCT

PORT

DOWN

MENU

DOWN

MENU

CONFIG_MENU:

CNCT (blinking)

PORT

PASS 2

DOWN

MENU

MENU

CONFIG_MENU:

PORT (blinking)

PASS 2

SCRL

DOWN

2

MENU

2

ENTER

SCROLL_EDIT:

SCRL yes or no

(choice blinking if edit)

DOWN or

RIGHT 3 toggle scroll setting

ENTER

MENU

ENTER

ENTER

ENTER

DOWN increment blinking digit

CTN_EDIT:

CT-N

####

(one # blinking if edit)

RIGHT blink next digit

CTD_SHOW:

CT-D

1 or 5

ENTER

ENTER

DOWN increment blinking digit

PTN_EDIT:

PT-N

####

(one # blinking if edit)

RIGHT blink next digit

ENTER

DOWN increment blinking digit

PTD_EDIT:

PT-D

####

(one # blinking if edit)

ENTER

RIGHT blink next digit

CT_MULT_EDIT:

CT-S

1 or 10 or 100

(choice blinking if edit)

DOWN or

RIGHT show next choice

PT_MULT_EDIT:

PT-S

1 or 10 or 100 or 1000

(choice blinking if edit)

DOWN or

RIGHT show next choice

ENTER

ENTER

ENTER

CONNECT_EDIT:

CNCT

1 of 3 choices

(choice blinking if edit)

DOWN or

RIGHT show next choice

CNCT choices:

3 EL WYE,

2 CT DEL,

2.5EL WYE

ENTER

ENTER

DOWN increment blinking digit

ADDRESS_EDIT:

ADR

###

(one # blinking if edit)

RIGHT blink next digit

ENTER

PROT choices:

MOD RTU,

MOD ASCI,

DNP

ENTER

BAUD_EDIT:

BAUD

##.#

(choice blinking if edit)

DOWN or

RIGHT show next choice

PROTOCOL_EDIT:

PROT

1 of 3 choices

(choice blinking if edit)

DOWN or

RIGHT show next choice

CONFIG_MENU:

PASS

2

(blinking)

SCRL

CT

ENTER

CONFIG_MENU screen scrolls through 6 choices, showing 3 at a time. The top choice is always the

"active" one, indicated by blinking the legend.

DOWN increment blinking digit

PASSWORD_EDIT:

PASS

#### (one # blinking)

RIGHT blink next digit

ENTER

2

Notes:

1. Initial access is view-only. View access shows the existing settings. At the first attempt to change a setting (DOWN or RIGHT pressed), password is requested (if enabled) and access changes to edit. Edit access blinks the digit or list choice eligible for change and lights the PRG LED.

2. Skip over password edit screen and menu selection if access is view-only or if password is disabled.

3. Scroll setting may be changed with view or edit access.

4. ENTER accepts an edit; MENU abandons it.

MENU any changes?

yes

SAVE_YES:

STOR

ALL?

yes (blinking)

MENU

(per row of the originating screen)

ENTER save new configuration first DOWN or RIGHT in view access (if password required)

DOWN

CFG_ENTER_PW:

PASS

### (one # blinking) increment blinking digit

ENTER

See Note 1

RIGHT blink next digit yes no

MENU

RIGHT RIGHT

SAVE_CONFIRM:

STOR

ALL

DONE is password correct?

to the originating

EDIT screen to Main Menu see page A-2

MENU

STOR

SAVE_NO:

ALL?

no (blinking)

ENTER

2 sec.

reboot no to previous operating mode screen see page A-3 or A-4

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 A-5

A: Shark® 200-S Meter Navigation Maps

This page intentionally left blank.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc # E149721 A-6

B: Modbus Map and Retrieving Logs

B: Modbus Map and Retrieving Logs

B.1: Introduction

The Modbus Map for the Shark® 200S meter gives details and information about the possible readings of the meter and its programming. The Shark® 200S meter can be programmed using the buttons on the face of the meter (Chapter 7), or by using software (Chapter 5).

B.2: Modbus Register Map Sections

The Shark® 200S meter's Modbus Register map includes the following sections:

Fixed Data Section, Registers 1- 47, details the meter's Fixed Information.

Meter Data Section, Registers 1000 - 12031, details the meter's Readings, including

Primary Readings, Energy Block, Demand Block, Phase Angle Block, Status Block,

Minimum and Maximum in Regular and Time Stamp Blocks, and Accumulators.

Operating mode readings are described in Section 7.2.6.

Commands Section, Registers 20000 - 26011, details the meter's Resets Block,

Programming Block, Other Commands Block and Encryption Block.

Programmable Settings Section, Registers 30000 - 33575, details all the setups you can program to configure your meter.

Secondary Readings Section, Registers 40001 - 40100, details the meter's Secondary

Readings.

Log Retrieval Section, Registers 49997 - 51127, details log and retrieval. See Section

B.5 for instructions on retrieving logs.

B.3: Data Formats

ASCII:

SINT16/UINT16:

ASCII characters packed 2 per register in high, low order and without any termination characters

16-bit signed/unsigned integer

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 1

B: Modbus Map and Retrieving Logs

SINT32/UINT32:

FLOAT:

32-bit signed/unsigned integer spanning 2 registers - the lower-addressed register is the high order half

32-bit IEEE floating point number spanning 2 registers - the lower-addressed register is the high order half (i.e., contains the exponent)

B.4: Floating Point Values

Floating Point Values are represented in the following format:

Register 0 1

Byte

Bit

0

7 6 5 4 3 2 1 0

1

7 6 5 4 3 2 1 0

0

7 6 5 4 3 2 1 0

1

7 6 5 4 3 2 1 0

Meaning s

sign e e e exponent e e e e e m m m m m m m m m m m m m m m m m m m m m m m mantissa

The formula to interpret a Floating Point Value is:

-1

sign

x 2

exponent-127

x 1.mantissa = 0x0C4E11DB9

-1

sign

x 2

137-127

x 1· 1000010001110110111001

-1 x 2

10

x 1.75871956

-1800.929

Register

Byte

Bit

0x0C4E1 0x01DB9

0x0C4

7 6 5 4 3 2 1 0

0x0E1

7 6 5 4 3 2 1 0

0x01D

7 6 5 4 3 2 1 0

0x0B9v

7 6 5 4 3 2 1 0

Meaning

1 s

1 0 0 0 1 0 0 1 1 1 0 0 0 0 1 0 0 0 1 1 1 0 1 1 0 1 1 1 0 0 1 e e e e e e e e m m m m m m m m m m m m m m m m m m m m m m m

sign exponent mantissa

1 0x089 + 137 0b011000010001110110111001

Formula Explanation:

C4E11DB9 (hex) 11000100 11100001 00011101 10111001

(binary)

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 2

B: Modbus Map and Retrieving Logs

The sign of the mantissa (and therefore the number) is 1, which represents a negative value.

The Exponent is 10001001 (binary) or 137 decimal.

The Exponent is a value in excess 127. So, the Exponent value is 10.

The Mantissa is 11000010001110110111001 binary.

With the implied leading 1, the Mantissa is (1).611DB9 (hex).

The Floating Point Representation is therefore -1.75871956 times 2 to the 10.

Decimal equivalent: -1800.929

NOTES:

• Exponent = the whole number before the decimal point.

• Mantissa = the positive fraction after the decimal point.

B.5: Retrieving Logs Using the Shark® 200S Meter's Modbus Map

This section describes the log interface system of the Shark® 200S meter from a programming point of view. It is intended for programmers implementing independent drivers for log retrieval from the meter. It describes the meaning of the meter's

Modbus Registers related to log retrieval and conversion, and details the procedure for retrieving a log's records.

NOTES:

• All references assume the use of Modbus function codes 0x03, 0x06, and 0x10, where each register is a 2 byte MSB (Most Significant Byte) word, except where otherwise noted.

• The carat symbol (^) notation is used to indicate mathematical "power." For example, 2^8 means 28; which is 2 x 2 x 2 x 2 x 2 x 2 x 2 x 2, which equals 256.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 3

B: Modbus Map and Retrieving Logs

B.5.1: Data Formats

Time stamp: Stores a date from 2000 to 2099. Time stamp has a Minimum resolution of 1 second.

Byte 0 1 2 3 4 5

Value Year Month Day

Range 0-99 (+2000) 1-12 1-31

Hour

0-23

Minute

0-59

Second

0-59

Mask 0x7F 0x0F 0x1F 0x1F 0x3F 0x3F

The high bits of each time stamp byte are used as flags to record meter state information at the time of the time stamp. These bits should be masked out, unless needed.

B.5.2: Shark® 200S Meter Logs

The Shark® 200S meter has 5 logs: System Event, Alarm (Limits), and 3 Historical logs. Each log is described below.

1.

System Event (0)

: The System Event log is used to store events which happen in, and to, the meter. Events include Startup, Reset Commands, Log Retrievals, etc.

The System Event Log Record takes 20 bytes, 14 bytes of which are available when the log is retrieved.

Byte

Value

0 1 2 3 4 5 6 timestamp Group

7

Event

8

Mod

9

Chan

10

Param1

11

Param2

12

Param3

13

Param4

NOTE:

The complete Systems Events table is shown in Section B.5.5, step 1, on page

B-19.

2.

Alarm Log (1):

The Alarm Log records the states of the 8 Limits programmed in the meter.

• Whenever a limit goes out (above or below), a record is stored with the value that caused the limit to go out.

• Whenever a limit returns within limit, a record is stored with the "most out of limit" value for that limit while it was out of limit.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 4

B: Modbus Map and Retrieving Logs

The Alarm Log Record uses 16 bytes, 10 bytes of which are available when the log is retrieved.

Byte 0 1 2 3 4 5 6

Value timestamp direction

7 limit#

8 9

Value%

The limit # byte is broken into a type and an ID.

Bit 0 1 2 3 4 5 6 7

Value type 0 0 0 0 Limit ID

3.

Historical Log 1 (2)

: The Historical Log records the values of its assigned registers at the programmed interval.

NOTE:

See Section B.5.3, Number 1, for details on programming and interpreting the log.

Byte 0 1 2 3 4 5 6 N

Value timestamp values . . .

4.

Historical Log 2 (3)

: Same as Historical Log 1.

5.

Historical Log 3 (4)

: Same as Historical Log 1.

B.5.3: Block Definitions

This section describes the Modbus Registers involved in retrieving and interpreting a

Shark® 200S Meter Log. Other sections refer to certain 'values' contained in this section. See the corresponding value in this section for details.

NOTES:

• “Register” is the Modbus Register Address in 0-based Hexadecimal notation. To convert it to 1-based decimal notation, convert from hex16 to decimal10 and add

1. For example: 0x03E7 = 1000.

• “Size” is the number of Modbus Registers (2 byte) in a block of data.

Historical Log Programmable Settings:

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 5

B: Modbus Map and Retrieving Logs

The Historical Logs are programmed using a list of Modbus Registers that will be copied into the Historical Log record. In other words, Historical Log uses a direct copy of the Modbus Registers to control what is recorded at the time of record capture.

To supplement this, the programmable settings for the Historical Logs contain a list of descriptors, which group registers into items. Each item descriptor lists the data type of the item, and the number of bytes for that item. By combining these two lists, the

Historical Log record can be interpreted.

For example: Registers 0x03E7 and 0x03E8 are programmed to be recorded by the historical log. The matching descriptor gives the data type as float, and the size as 4 bytes. These registers program the log to record "Primary Readings Volts A-N."

Historical Log Blocks:

Start Register: 0x7917 (Historical Log 1)

0x79D7 (Historical Log 2)

0x7A97 (Historical Log 3)

192 registers per log (384 bytes) Block Size:

The Historical Log programmable settings are comprised of 3 blocks, one for each log.

Each is identical to the others, so only Historical Log 1 is described here. All register addresses in this section are given as the Historical Log 1 address (0x7917).

Each Historical Log Block is composed of 3 sections: The header, the list of registers to log, and the list of item descriptors.

Header:

Registers:

Size:

Byte

Value

0

# Registers

0x7917 - 0x7918

2 registers

1

# Sectors

2 3

Interval

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 6

B: Modbus Map and Retrieving Logs

• # Registers: The number of registers to log in the record. The size of the record in memory is [12 + (# Registers x 2)]. The size during normal log retrieval is [6 + (#

Registers x 2)]. If this value is 0, the log is disabled. Valid values are {0-117}.

• # Sectors: The number of Flash Sectors allocated to this log. Each sector is 64kb, minus a sector header of 20 bytes. 15 sectors are available for allocation between

Historical Logs 1, 2, and 3. The sum of all Historical Logs may be less than 15. If this value is 0, the log is disabled. Valid values are {0-15}.

• Interval: The interval at which the Historical Log's Records are captured. This value is an enumeration:

0x01

0x02

1 minute

3 minute

0x04

0x08

0x10

0x20

5 minute

10 minute

15 minute

30 minute

60 minute 0x40

Register List:

Registers:

Size:

0x7919 - 0x798D

1 register per list item, 117 list items

The Register List controls what Modbus Registers are recorded in each record of the

Historical Log. Since many items, such as Voltage, Energy, etc., take up more than 1 register, multiple registers need to be listed to record those items.

For example: Registers 0x03E7 and 0x03E8 are programmed to be recorded by the historical log. These registers program the log to record "Primary Readings Volts A-N."

• Each unused register item should be set to 0x0000 or 0xFFFF to indicate that it should be ignored.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 7

B: Modbus Map and Retrieving Logs

• The actual size of the record, and the number of items in the register list which are used, is determined by the # registers in the header.

• Each register item is the Modbus Address in the range of 0x0000 to 0xFFFF.

Item Descriptor List:

Registers:

Size:

0x798E - 0x79C8

1 byte per item, 117 bytes (59 registers)

While the Register List describes what to log, the Item Descriptor List describes how to interpret that information. Each descriptor describes a group of register items, and what they mean.

Each descriptor is composed of 2 parts:

• Type: The data type of this descriptor, such as signed integer, IEEE floating point, etc. This is the high nibble of the descriptor byte, with a value in the range of 0-14.

If this value is 0xFF, the descriptor should be ignored.

0

1

ASCII: An ASCII string, or byte array

Bitmap: A collection of bit flags

2

3

Signed Integer: A 2's Complement integer

Float: An IEEE floating point

4 Energy: Special Signed Integer, where the value

is adjusted by the energy settings in the meter's

Programmable Settings.

5 Unsigned Integer

6 Signed Integer 0.1 scale: Special Signed Integer, where the value is divided by 10 to give a 0.1

scale.

Unused 7-14

15 Disabled: used as end list marker.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 8

B: Modbus Map and Retrieving Logs

• Size: The size in bytes of the item described. This number is used to determine the pairing of descriptors with register items.

For example: If the first descriptor is 4 bytes, and the second descriptor is 2 bytes, then the first 2 register items belong to the 1st descriptor, and the 3rd register item belongs to the 2nd descriptor.

NOTE:

As can be seen from the example, above, there is not a 1-to-1 relation between the register list and the descriptor list. A single descriptor may refer to multiple register items.

Register Items

0x03C7/

0x03C8

0x1234

Descriptors

Float, 4 byte

Signed Int, 2 byte

NOTE:

The sum of all descriptor sizes must equal the number of bytes in the data portion of the Historical Log record.

Log Status Block:

The Log Status Block describes the current status of the log in question. There is one header block for each of the logs. Each log's header has the following base address:

Log

Alarms:

Base Address

0xC737

System:

Historical 1:

Historical 2:

Historical 3:

Bytes Value

0-3 Max Records

0xC747

0xC757

0xC767

0xC777

Type Range

UINT32 0 to 4,294,967,294

# Bytes

4

4-7 Number of Records Used UINT32 1 to 4,294,967,294 4

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 9

B: Modbus Map and Retrieving Logs

8-9 Record Size in Bytes

10-11 Log Availability

UINT16 4 to 250

UINT16

12-17 Timestamp, First Record TSTAMP 1Jan2000 - 31Dec2099 6

18-23 Timestamp, Last Record TSTAMP 1Jan2000 - 31Dec2099 6

2

2

24-31 Reserved 8

• Max Records: The maximum number of records the log can hold given the record size, and sector allocation. The data type is an unsigned integer from 0 - 2^32.

• Records Used: The number of records stored in the log. This number will equal the

Max Records when the log has filled. This value will be set to 1 when the log is reset. The data type is an unsigned integer from 1 - 2^32.

NOTE:

The first record in every log before it has rolled over is a "dummy" record, filled with all 0xFF's. When the log is filled and rolls over, this record is overwritten.

• Record Size: The number of bytes in this record, including the timestamp. The data type is an unsigned integer in the range of 14 - 242.

• Log Availability: A flag indicating if the log is available for retrieval, or if it is in use by another port.

0

1

Log Available for retrieval

In use by COM1 (IrDA)

2 In use by COM2 (RS485)

0xFFFF Log Not Available - the log cannot be retrieved.

This indicates that the log is disabled.

NOTE:

To query the port by which you are currently connected, use the Port ID register:

Register:

Size:

0x1193

1 register

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 10

B: Modbus Map and Retrieving Logs

Description: A value from 1-4, which enumerates the port that the requestor is currently connected on.

NOTES:

• When Log Retrieval is engaged, the Log Availability value will be set to the port that engaged the log. The Log Availability value will stay the same until either the log has been disengaged, or 5 minutes have passed with no activity. It will then reset to 0 (available).

• Each log can only be retrieved by one port at a time.

• Only one log at a time can be retrieved.

• First Timestamp: Timestamp of the oldest record.

• Last Timestamp: Timestamp of the newest record.

Log Retrieval Block:

The Log Retrieval Block is the main interface for retrieving logs. It is comprised of 2 parts: the header and the window. The header is used to program the particular data the meter presents when a log window is requested. The window is a sliding block of data that can be used to access any record in the specified log.

Session Com Port

: The Shark® 200S meter's Com Port which is currently retrieving logs. Only one Com Port can retrieve logs at any one time.

0

1

Registers:

Size:

0xC34E - 0xC34E

1 register

No Session Active

COM1 (IrDA)

2 COM2 (RS-485)

To get the current Com Port, see the NOTE on querying the port, on the previous page.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 11

B: Modbus Map and Retrieving Logs

Log Retrieval Header:

The Log Retrieval Header is used to program the log to be retrieved, the record(s) of that log to be accessed, and other settings concerning the log retrieval.

Registers:

Size:

0xC34F - 0xC350

2 registers

Bytes Value

0-1 Log Number,

Enable,

Scope

Type Format

UINT16 nnnnnnnn esssssss

2-3 Records per

Window,

Number of

Repeats

UINT16 wwwwwwww nnnnnnnn

Description nnnnnnnn - log to retrieve, e - retrieval session enable sssssss - retrieval mode wwwwwwww - records per window, nnnnnnnn - repeat count

# Bytes

2

2

2

3

4

• Log Number: The log to be retrieved. Write this value to set which log is being retrieved.

0

1

System Events

Alarms

Historical Log 1

Historical Log 2

Historical Log 3

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 12

B: Modbus Map and Retrieving Logs

• Enable: This value sets if a log retrieval session is engaged (locked for retrieval) or disengaged (unlocked, read for another to engage). Write this value with 1(enable) to begin log retrieval. Write this value with 0(disable) to end log retrieval.

0

1

Disable

Enable

• Scope: Sets the amount of data to be retrieved for each record. The default should be 0 (normal).

0

1

2

Normal

Timestamp Only

Image

• Normal [0]: The default record. Contains a 6-byte timestamp at the beginning, then N data bytes for the record data.

• Timestamp [1]: The record only contains the 6-byte timestamp. This is most useful to determine a range of available data for non-interval based logs, such as Alarms and System Events.

• Image [2]: The full record, as it is stored in memory. Contains a 2-byte checksum, 4-byte sequence number, 6-byte timestamp, and then N data bytes for the record data.

• Records Per Window: The number of records that fit evenly into a window. This value is set-able, as less than a full window may be used. This number tells the retrieving program how many records to expect to find in the window.

(RecPerWindow x RecSize) = #bytes used in the window.

This value should be ((123 x 2) \ recSize), rounded down.

For example, with a record size of 30, the RecPerWindow = ((123 x 2) \ 30) = 8.2

~= 8

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 13

B: Modbus Map and Retrieving Logs

• Number of Repeats: Specifies the number of repeats to use for the Modbus Function Code 0x23 (35). Since the meter must pre-build the response to each log window request, this value must be set once, and each request must use the same repeat count. Upon reading the last register in the specified window, the record index will increment by the number of repeats, if auto-increment is enabled. Section B.5.4.2 has additional information on Function Code 0x23.

0

1

2-8

Disables auto-increment

No Repeat count, each request will only get 1 window.

2-8 windows returned for each Function Code

0x23 request.

Bytes Value

0-3 Offset of

First Record in Window

Type

UINT32

Format ssssssss nnnnnnnn nnnnnnnn nnnnnnnn

Description ssssssss - window status nn…nn -

24-bit record index number.

# Bytes

4

246 4-249 Log Retrieve

Window

UINT16

Log Retrieval Window Block:

The Log Retrieval Window block is used to program the data you want to retrieve from the log. It also provides the interface used to retrieve that data.

Registers:

Size:

0xC351 - 0xC3CD

125 registers

• Window Status: The status of the current window. Since the time to prepare a window may exceed an acceptable modbus delay (1 second), this acts as a state flag, signifying when the window is ready for retrieval. When this value indicates that the window is not ready, the data in the window should be ignored. Window Status is Read-only, any writes are ignored.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 14

B: Modbus Map and Retrieving Logs

0

0xFF

Window is Ready

Window is Not Ready

• Record Number: The record number of the first record in the data window. Setting this value controls which records will be available in the data window.

• When the log is engaged, the first (oldest) record is "latched." This means that record number 0 will always point to the oldest record at the time of latching, until the log is disengaged (unlocked).

• To retrieve the entire log using auto-increment, set this value to 0, and retrieve the window repeatedly, until all records have been retrieved.

NOTES:

• When auto-increment is enabled, this value will automatically increment so that the window will "page" through the records, increasing by

RecordsPerWindow each time that the last register in the window is read.

• When auto-increment is not enabled, this value must be written-to manually, for each window to be retrieved.

• Log Retrieval Data Window: The actual data of the records, arranged according to the above settings.

B.5.4: Log Retrieval

Log Retrieval is accomplished in 3 basic steps:

1. Engage the log.

2. Retrieve each of the records.

3. Disengage the log.

B.5.4.1: Auto-Increment

In EIG's traditional Modbus retrieval system, you write the index of the block of data to retrieve, then read that data from a buffer (window). To improve the speed of retrieval, the index can be automatically incremented each time the buffer is read.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 15

B: Modbus Map and Retrieving Logs

In the Shark® 200S meter, when the last register in the data window is read, the record index is incremented by the Records per Window.

B.5.4.2: Modbus Function Code 0x23

QUERY

Field Name Example (Hex)

Slave Address

Function

Starting Address Hi

Starting Address Lo

01

23

C3

51

# Points Hi

# Points Lo

00

7D

Repeat Count

RESPONSE

Field Name

04

Example (Hex)

01 Slave Address

Function 23

03 # Bytes Hi

# Bytes Lo E0

...

Data

Function Code 0x23 is a user defined Modbus function code, which has a format similar to Function Code 0x03, except for the inclusion of a "repeat count." The repeat count (RC) is used to indicate that the same N registers should be read RC number of times. (See the Number of Repeats bullet on page B-14.)

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 16

B: Modbus Map and Retrieving Logs

NOTES:

• By itself this feature would not provide any advantage, as the same data will be returned RC times. However, when used with auto-incrementing, this function condenses up to 8 requests into 1 request, which decreases communication time, as fewer transactions are being made.

• Keep in mind that the contents of the response data is the block of data you requested, repeated N times. For example, when retrieving log windows, you normally request both the window index, and the window data. This means that the first couple of bytes of every repeated block will contain the index of that window.

• In the Shark® 200S meter repeat counts are limited to 8 times for Modbus RTU, and 4 times for Modbus ASCII.

The response for Function Code 0x23 is the same as for Function Code 0x03, with the data blocks in sequence.

IMPORTANT!

Before using Function Code 0x23, always check to see if the current connection supports it. Some relay devices do not support user defined function codes; if that is the case, the message will stall. Other devices don't support 8 repeat counts.

B.5.4.3: Log Retrieval Procedure

The following procedure documents how to retrieve a single log from the oldest record to the newest record, using the "normal" record type (see

Scope

). All logs are retrieved using the same method. See Section B.5.4.4 for a Log Retrieval example.

NOTES:

• This example uses auto-increment.

• In this example, Function Code 0x23 is not used.

• You will find referenced topics in Section B.5.3. Block Definitions.

• Modbus Register numbers are listed in brackets.

1. Engage the Log:

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 17

B: Modbus Map and Retrieving Logs a. Read the Log Status Block.

i.. Read the contents of the specific logs' status block [0xC737+, 16 reg] (see Log Headers). ii. Store the # of Records Used, the Record Size, and the Log Availability. iii. If the Log Availability is not 0, stop Log Retrieval; this log is not available at this time. If Log Availability is 0, proceed to step 1b

(Engage the log).

This step is done to ensure that the log is available for retrieval, as well as retrieving information for later use.

b. Engage the log: write log to engage to Log Number, 1 to Enable, and the desired mode to Scope (default 0 (Normal)) [0xC34F, 1 reg]. This is best done as a single-register write.

This step will latch the first (oldest) record to index 0, and lock the log so that only this port can retrieve the log, until it is disengaged.

c. Verify the log is engaged: read the contents of the specific logs' status block

[0xC737+, 16 reg] again to see if the log is engaged for the current port (see

Log Availability). If the Log is not engaged for the current port, repeat step 1b

(Engage the log).

d. Write the retrieval information.

i. Compute the number of records per window, as follows:

RecordsPerWindow = (246 \ RecordSize)

• If using 0x23, set the repeat count to 2-8. Otherwise, set it to 1.

• Since we are starting from the beginning for retrieval, the first record index is 0.

ii. Write the Records per window, the Number of repeats (1), and

Record Index (0) [0xC350, 3 reg].

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 18

B: Modbus Map and Retrieving Logs

This step tells the Shark® 200S meter what data to return in the window.

2. Retrieve the records: a. Read the record index and window: read the record index, and the data window

[0xC351, 125 reg].

• If the meter Returns a Slave Busy Exception, repeat the request.

• If the Window Status is 0xFF, repeat the request.

• If the Window Status is 0, go to step 2b (Verify record index).

NOTES:

• We read the index and window in 1 request to minimize communication time, and to ensure that the record index matches the data in the data window returned.

• Space in the window after the last specified record (RecordSize x Record-

PerWindow) is padded with 0xFF, and can be safely discarded. b. Verify that the record index incremented by Records Per Window. The record index of the retrieved window is the index of the first record in the window. This value will increase by Records Per Window each time the window is read, so it should be 0, N, N x 2, N x 3 . . . for each window retrieved.

• If the record index matches the expected record index, go to step 2c

(Compute next expected record index).

• If the record index does not match the expected record index, then go to step 1d (Write the retrieval information), where the record index will be the same as the expected record index. This will tell the Shark® 200S meter to repeat the records you were expecting. c. Compute next Expected Record Index.

• If there are no remaining records after the current record window, go to step 3 (Disengage the log).

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 19

B: Modbus Map and Retrieving Logs

• Compute the next expected record index by adding Records Per Window, to the current expected record index. If this value is greater than the number of records, re-size the window so it only contains the remaining records and go to step 1d (Write the retrieval information), where the

Records Per Window will be the same as the remaining records.

3. Disengage the log: write the Log Number (of log being disengaged) to the Log

Index and 0 to the Enable bit [0xC34F, 1 reg].

B.5.4.4: Log Retrieval Example

The following example illustrates a log retrieval session. The example makes the following assumptions:

• Log Retrieved is Historical Log 1 (Log Index 2).

• Auto-Incrementing is used.

• Function Code 0x23 is not used (Repeat Count of 1).

• The Log contains Volts-AN, Volts-BN, Volts-CN (12 bytes).

• 100 Records are available (0-99).

• COM Port 2 (RS485) is being used (see Log Availability).

• There are no Errors.

• Retrieval is starting at Record Index 0 (oldest record).

• Protocol used is Modbus RTU. The checksum is left off for simplicity.

• The Shark® 200S meter is at device address 1.

• No new records are recorded to the log during the log retrieval process.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 20

B: Modbus Map and Retrieving Logs

1. Read [0xC757, 16 reg], Historical Log 1 Header Block.

Send:

Command

:

Register Address:

# Registers:

0103 C757 0010

0xC757

16

---------------------------------------------------

Receive

: 010320 00000100 00000064 0012 0000

060717101511 060718101511

0000000000000000

Data

:

Max Records: 0x100 = 256 records maximum.

Num Records:

Record Size:

Log Availability:

First Timestamp:

0x64 = 100 records currently logged.

0x12 = 18 bytes per record.

0x00 = 0, not in use, available for retrieval.

0x060717101511 = July 23, 2006, 16:21:17

Last Timestamp: 0x060717101511 = July 24, 2006, 16:21:17

NOTE

: This indicates that Historical Log 1 is available for retrieval.

2. Write 0x0280 -> [0xC34F, 1 reg], Log Enable.

Send

:

Command

:

Register Address:

# Registers:

Data

:

Log Number:

0106 C34F 0280

0xC34F

1 (Write Single Register Command)

2 (Historical Log 1)

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 21

B: Modbus Map and Retrieving Logs

Enable:

Scope:

1 (Engage log)

0 (Normal Mode)

---------------------------------------------------

Receive

: 0106C34F0280 (echo)

NOTE

: This engages the log for use on this COM Port, and latches the oldest record as record index 0.

3. Read [0xC757, 16 reg], Availability is 0.

Send

:

Command

:

Register Address:

# Registers:

0103 C757 0010

0xC757

16

---------------------------------------------------

Receive

: 010320 00000100 00000064 0012 0002

060717101511 060718101511

0000000000000000

Data

:

Max Records: 0x100 = 256 records maximum.

Num Records:

Record Size:

0x64 = 100 records currently logged.

0x12 = 18 bytes per record.

Log Availability:

First Timestamp:

0x02 = 2, In use by COM2, RS485 (the current port)

0x060717101511 = July 23, 2006, 16:21:17

Last Timestamp: 0x060717101511 = July 24, 2006, 16:21:17

NOTE

: This indicates that the log has been engaged properly in step 2. Proceed to retrieve the log.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 22

B: Modbus Map and Retrieving Logs

4. Compute #RecPerWin as (246\18)=13. Write 0x0D01 0000 0000 -> [0xC350, 3 reg] Write Retrieval Info. Set Current Index as 0.

Send

:

Command

:

Register Address:

# Registers:

Data

:

Records per Window:

0110 C350 0003 06 0D01 00 000000

0xC350

3, 6 bytes

# of Repeats:

Window Status:

Record Index:

13. Since the window is 246 bytes, and the record is 18 bytes, 246\18 = 13.66, which means that

13 records evenly fit into a single window. This is

234 bytes, which means later on, we only need to read 234 bytes (117 registers) of the window to retrieve the records.

1. We are using auto-increment (so not 0), but not function code 0x23.

0 (ignore)

0, start at the first record.

----------------------------------------------------

Receive

:

NOTES

:

0110C3500003 (command ok)

• This sets up the window for retrieval; now we can start retrieving the records.

• As noted above, we compute the records per window as 246\18 = 13.66, which is rounded to 13 records per window. This allows the minimum number of requests to be made to the meter, which increases retrieval speed.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 23

B: Modbus Map and Retrieving Logs

5. Read [0xC351, 125 reg], first 2 reg is status/index, last 123 reg is window data.

Status OK.

Send

:

Command

:

Register Address:

Data:

Record 1:

Timestamp:

0103 C351 007D

0xC351

0x7D, 125 registers # Registers:

---------------------------------------------------

Receive

: 0103FA 00000000

060717101511FFFFFFFFFFFFFFFFFFFFFFFF

06071710160042FAAACF42FAAD1842FAA9A8 . . .

Data

:

Window Status: 0x00 = the window is ready.

Index: 0x00 = 0, The window starts with the 0'th record, which is the oldest record.

The next 18 bytes is the 0'th record (filler).

Record 0:

Timestamp: 0x060717101511, = July 23, 2006, 16:21:17

This record is the "filler" record. It is used by the meter so that there is never 0 records. It should be ignored. It can be identified by the data being all 0xFF.

NOTE:

Once a log has rolled over, the 0'th record will be a valid record, and the filler record will disappear.

The next 18 bytes is the 1'st record.

0x060717101600 July 23, 2006, 16:22:00

Data:

Volts AN:

Volts BN:

0x42FAAACF, float = 125.33~

0x42FAAD18, float = 125.33~

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 24

B: Modbus Map and Retrieving Logs

Volts CN:

. . . 13 records

NOTES

:

0x42FAA9A8, float = 125.33~

• This retrieves the actual window. Repeat this command as many times as necessary to retrieve all of the records when auto-increment is enabled.

• Note the filler record. When a log is reset (cleared) in the meter, the meter always adds a first "filler" record, so that there is always at least 1 record in the log. This

"filler" record can be identified by the data being all 0xFF, and it being index 0. If a record has all 0xFF for data, the timestamp is valid, and the index is NOT 0, then the record is legitimate.

• When the "filler" record is logged, its timestamp may not be "on the interval." The next record taken will be on the next "proper interval," adjusted to the hour. For example, if the interval is 1 minute, the first "real" record will be taken on the next minute (no seconds). If the interval is 15 minutes, the next record will be taken at

:15, :30, :45, or :00 - whichever of those values is next in sequence.

6. Compare the index with Current Index.

NOTES

:

• The Current Index is 0 at this point, and the record index retrieved in step 5 is 0: thus we go to step 8.

• If the Current Index and the record index do not match, go to step 7. The data that was received in the window may be invalid, and should be discarded.

7. Write the Current Index to [0xC351, 2 reg].

Send

:

Command

:

Register Address:

# Registers:

Data

:

0110 C351 0002 04 00 00000D

0xC351

2, 4 bytes

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 25

B: Modbus Map and Retrieving Logs

Window Status:

Record Index:

0 (ignore)

0x0D = 13, start at the 14th record.

----------------------------------------------------

Receive

:

NOTES

:

0110C3510002 (command ok)

• This step manually sets the record index, and is primarily used when an out-oforder record index is returned on a read (step 6).

• The example assumes that the second window retrieval failed somehow, and we need to recover by requesting the records starting at index 13 again.

8. For each record in the retrieved window, copy and save the data for later interpretation.

9. Increment Current Index by RecordsPerWindow.

NOTES

:

• This is the step that determines how much more of the log we need to retrieve.

• On the first N passes, Records Per Window should be 13 (as computed in step 4), and the current index should be a multiple of that (0, 13, 26, . . .). This amount will decrease when we reach the end (see step 10).

• If the current index is greater than or equal to the number of records (in this case

100), then all records have been retrieved; go to step 12. Otherwise, go to step 10 to check if we are nearing the end of the records.

10. If number records - current index < RecordsPerWindow, decrease to match.

NOTES

:

• Here we bounds-check the current index, so we don't exceed the records available.

• If the number of remaining records (#records - current index) is less than the

Records per Window, then the next window is the last, and contains less than a full window of records. Make records per window equal to remaining records

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 26

B: Modbus Map and Retrieving Logs

(#records-current index). In this example, this occurs when current index is 91

(the 8'th window). There are now 9 records available (100-91), so make Records per Window equal 9.

11. Repeat steps 5 through 10.

NOTES

:

• Go back to step 5, where a couple of values have changed.

Pass CurIndex FirstRecIndex RecPerWindow

0 0 0 13

1 13 13 13

2 26 26

3 39 39

4 52 52

5 65 65

13

13

13

13

6 78 78

7 91 91

13

9

8 100 ------ -------

• At pass 8, since Current Index is equal to the number of records (100), log retrieval should stop; go to step 12 (see step 9 Notes).

12. No more records available, clean up.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 27

B: Modbus Map and Retrieving Logs

13. Write 0x0000 -> [0xC34F, 1 reg], disengage the log.

Send

:

Command

:

Register Address:

0106 C34F 0000

0xC34F

1 (Write Single Register Command) # Registers:

Data

:

Log Number: 0 (ignore)

0 (Disengage log) Enable:

Scope: 0 (ignore)

----------------------------------------------------

Receive

:

NOTES

:

0106C34F0000 (echo)

• This disengages the log, allowing it to be retrieved by other COM ports.

• The log will automatically disengage if no log retrieval action is taken for 5 minutes.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 28

B: Modbus Map and Retrieving Logs

B.5.5: Log Record Interpretation

The records of each log are composed of a 6 byte timestamp, and N data. The content of the data portion depends on the log.

System Event Record:

Byte

Value

0 1 2 3 4 5 6 timestamp Group

7

Event

8

Mod

9

Chan

10

Param1

11

Param2

12

Param3

13

Param4

Size

: 14 bytes (20 bytes image).

Data

: The System Event data is 8 bytes; each byte is an enumerated value.

• Group: Group of the event.

• Event: Event within a group.

• Modifier: Additional information about the event, such as number of sectors or log number.

• Channel: The port of the Shark® 200S meter that caused the event.

0 Firmware

1

2

7

COM 1 (IrDA)

COM 2 (RS485)

User (Face Plate)

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 29

B: Modbus Map and Retrieving Logs

Group

(Event group)

Param 1-4: These are defined for each event (see following table).

NOTE

: The System Log Record is 20 bytes, consisting of the Record Header (12 bytes) and Payload (8 bytes). The Timestamp (6 bytes) is in the header. Typically, software will retrieve only the timestamp and payload, yielding a 14-byte record. The table below shows all defined payloads.

Event

(Event within group)

Mod

(Event modifier)

Channel

(1-2 for

COMs, 7 for USER,

0 for FW)

Parm1 Parm2 Parm3 Parm4 Comments

0

0 0 0 FW version

Startup

Meter Run

Firmware

Startup

1

2

3

3

4

1

2

5

1

2

3

1

2

3 log# log# log#

0

0

0 sync method sync method

0

0

1-4

0

0

0

0 slot#

1-4

1-4

0-4

0-4, 7

0-4, 7

0-4

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF 0xFF

0xFF

1

(inputs) or 2

(outputs)

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

Log Activity

Reset

Log Retrieval

Begin

Log Retrieval

End

0xFF

0xFF

0xFF

0xFF

0xFF

Clock Activity

Clock Changed

Daylight Time

On

Daylight Time

Off

Auto Clock

Sync Failed

Auto Clock

Sync Resumed

0xFF

0xFF

0xFF

System Resets

Max & Min

Reset

Energy Reset

Accumulators

Reset

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 30

B: Modbus Map and Retrieving Logs

4

5

6

4

1

6

7

8

1

2

3

4

5

9

10

0

0

0

0

0 log # log # log # sector#

0

0

0

0

0

1

1-4, 7

1-4

1-4, 7

1-4, 7

1-4

0

0

0

0

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

Settings

Activity

Password

Changed

V-switch

Changed

Programmable Settings

Changed

Measurement

Stopped

FW version

Boot Activity

Exit to Boot

0xFF

# records discarded

0xFF

# records discarded error count

0xFF 0xFF

0xFF

0xFF

0xFF

0Xff

0xFF

0xFF

0xFF time in seconds time in seconds stimulus

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

Error Reporting & Recovery

Log Babbling

Detected

Babbling Log

Periodic

Summary

Log Babbling

End Detected

Flash Sector

Error

Flash Error

Counters

Reset

Flash Job

Queue

Overflow

Bad NTP

Configuration

0x88

3

4

1

2 sector# sector# sector# log#

0

0

0

0 log # log #

0xFF

0xFF erase count

0xFF 0xFF

0xFF

0xFF

0xFF

0xFF

0xFF

0xFF acquire sector release sector erase sector write log start record

• log# values: 0 = system log, 1 = alarms log, 2-4 = historical logs 1-3, 5 = I/O change log

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 31

B: Modbus Map and Retrieving Logs

• sector# values: 0-63

• slot# values: 1-2

NOTES

:

• The clock changed event shows the clock value just before the change in the Mod and Parm bytes. Parms are bit-mapped:

• b31 - b28

• b27 - b23

• b22

• b20 - b16 month day daylight savings time flag hour

• b13 - b8

• b5 - b0

• unused bits are always 0

• Sync method: 1 = NTP.

minute second

• Stimulus for a flash sector error indicates what the flash was doing when the error occurred: 1 = acquire sector, 2 = startup, 3 = empty sector, 4 = release sector, 5 = write data.

• Flash error counters are reset to zero in the unlikely event that both copies in

EEPROM are corrupted.

• The flash job queue is flushed (and log records are lost) in the unlikely event that the queue runs out of space.

• A "babbling log" is one that is saving records faster than the meter can handle long term. When babbling is detected, the log is frozen and no records are appended until babbling ceases. For as long as babbling persists, a summary of records discarded is logged every 60 minutes. Normal logging resumes when there have been no new append attempts for 30 seconds. Onset of babbling occurs when a log fills a flash sector in less than an hour (applies only to Alarm, I/O Change, Histori-

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 32

B: Modbus Map and Retrieving Logs cal, and Power Quality logs) or when a log grows so far beyond its normal bounds that it is in danger of crashing the system. This applies to all logs except the System log, which does not babble. While possible for the other logs during an extended log retrieval session, it is extremely unlikely to occur.

• Logging of diagnostic records may be suppressed via a bit in programmable settings.

Alarm Record

:

Byte 0 1 2 3 4 5 6

Value timestamp direction

7 limit#

8 9

Value%

Size

: 10 bytes (16 bytes image)

Data

: The Alarm record data is 4 bytes, and specifies which limit the event occurred on, and the direction of the event (going out of limit, or coming back into limit).

• Direction: The direction of the alarm event: whether this record indicates the limit going out, or coming back into limit.

1 Going out of limit

2 Coming back into limit

Bit 0 1 2 3 4 5 6 7

Value type 0 0 0 0 Limit ID

• Limit Type: Each limit (1-8) has both an above condition and a below condition.

Limit Type indicates which of those the record represents.

0

1

High Limit

Low Limit

• Limit ID: The specific limit this record represents. A value in the range 0-7, Limit ID represents Limits 1-8. The specific details for this limit are stored in the programmable settings.

• Value: Depends on the Direction:

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 33

B: Modbus Map and Retrieving Logs

• If the record is "Going out of limit," this is the value of the limit when the "Out" condition occurred.

Byte

Value

• If the record is "Coming back into limit," this is the "worst" value of the limit during the period of being "out": for High (above) limits, this is the highest value during the "out" period; for Low (below) limits, this is the lowest value during the “out" period.

0

Identifier

1 2 3

Above Setpoint

4 5

Above Hyst.

6 7

Below Setpoint

8 9

Below Hyst.

Interpretation of Alarm Data:

To interpret the data from the alarm records, you need the limit data from the

Programmable Settings [0x754B, 40 registers].

There are 8 limits, each with an Above Setpoint, and a Below Setpoint. Each setpoint also has a threshold (hysteresis), which is the value at which the limit returns "into" limit after the setpoint has been exceeded. This prevents "babbling" limits, which can be caused by the limit value fluttering over the setpoint, causing it to go in and out of limit continuously.

• Identifier: The first modbus register of the value that is being watched by this limit.

While any modbus register is valid, only values that can have a Full Scale will be used by the Shark® 200S meter.

• Above Setpoint: The percent of the Full Scale above which the value for this limit will be considered "out."

• Valid in the range of -200.0% to +200.0%

• Stored as an integer with 0.1 resolution. (Multiply % by 10 to get the integer, divide integer by 10 to get %. For example, 105.2% = 1052.)

• Above Hysteresis: The percent of the Full Scale below which the limit will return

"into" limit, if it is out. If this value is above the Above Setpoint, this Above limit will be disabled.

• Valid in the range of -200.0% to +200.0%.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 34

B: Modbus Map and Retrieving Logs

• Stored as an integer with 0.1 resolution. (Multiply % by 10 to get the integer, divide integer by 10 to get %. For example, 104.1% = 1041.)

• Below Setpoint: The percent of the Full Scale below which the value for this limit will be considered "out."

• Valid in the range of -200.0% to +200.0%.

• Stored as an integer with 0.1 resolution. (Multiply % by 10 to get the integer, divide integer by 10 to get %. For example, 93.5% = 935.)

• Below Hysteresis: The percent of the Full Scale above which the limit will return

"into" limit, if it is out. If this value is below the Below Setpoint, this Below limit will be disabled.

• Valid in the range of -200.0% to +200.0%.

• Stored as an integer with 0.1 resolution. (Multiply % by 10 to get the integer, divide integer by 10 to get %. For example, 94.9% = 949.)

NOTES

:

• The Full Scale is the "nominal" value for each of the different types of readings. To compute the Full Scale, use the following formulas:

Current

Voltage

[CT Numerator] x [CT Multiplier]

[PT Numerator] x [PT Multiplier]

Power 3-Phase (WYE)

Power 3-Phase (Delta)

Power Single Phase (WYE)

[CT Numerator] x [CT Multiplier] x [PT Numerator] x [PT Multiplier] x 3

[CT Numerator] x [CT Multiplier] x [PT Numerator] x [PT Multiplier] x 3 x sqrt(3)

[CT Numerator] x [CT Multiplier] x [PT Numerator] x [PT Multiplier]

Power Single Phase (Delta) [CT Numerator] x [CT Multiplier] x [PT Numerator] x [PT Multiplier] x sqrt(3)

Frequency (Calibrated at 60 Hz) 60

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 35

B: Modbus Map and Retrieving Logs

Frequency (Calibrated at 50 Hz) 50

Power Factor 1.0

Angles 180°

• To interpret a limit alarm fully, you need both the start and end record (for duration).

• There are a few special conditions related to limits:

• When the meter powers up, it detects limits from scratch. This means that multiple "out of limit" records can be in sequence with no "into limit" records.

Cross- reference the System Events for Power Up events.

• This also means that if a limit is "out," and it goes back in during the power off condition, no "into limit" record will be recorded.

• The "worst" value of the "into limit" record follows the above restrictions; it only represents the values since power up. Any values before the power up condition are lost.

Historical Log Record:

Byte 0 1 2 3 4 5 6 N

Value timestamp values . . .

Size

: 6+2 x N bytes (12+2 x N bytes), where N is the number of registers stored.

Data

: The Historical Log Record data is 2 x N bytes, which contains snapshots of the values of the associated registers at the time the record was taken. Since the meter uses specific registers to log, with no knowledge of the data it contains, the Programmable Settings need to be used to interpret the data in the record. See Historical Logs

Programmable Settings for details.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 36

B: Modbus Map and Retrieving Logs

B.5.6: Examples

Log Retrieval Section: send

: 01 03 75 40 00 08 -

Meter designation recv

: 01 03 10 4D 65 74 72 65 44 65 73 69 6E 67 5F 20 20 20 20 00 00

send

: :01 03 C7 57 00 10 -

Historical Log 1 status block recv

: :01 03 20 00 00 05 1E 00 00 05 1E 00 2C 00 00 06 08 17 51 08

00 06 08 18 4E 39 00 00 00 00 00 00 00 00 00 00 00

send

: :01 03 79 17 00 40 -

Historical Log 1 PS settings recv

: :01 03 80 13 01 00 01 23 75 23 76 23 77 1F 3F 1F 40 1F 41 1F

42 1F 43 1F 44 06 0B 06 0C 06 0D 06 0E 17 75 17 76 17 77 18

67 18 68 18 69 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00

00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00

00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00

00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00

00 00 00 00 00 00 00 00 00 00 00 00 00

send

: :01 03 79 57 00 40 - ""

recv

: :01 03 80 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00

00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00

00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00

00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00

00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00

00 00 00 00 00 00 00 00 00 00 00 00 00 62 62 62 34 34 34 44

44 62 62 62 62 62 62 00 00 00 00 00 00

send

: :01 03 75 35 00 01 -

Energy PS settings recv

: :01 03 02 83 31 00 00

send:

:01 03 11 93 00 01

- Connected Port ID recv

: :01 03 02 00 02 00 00

send

: :01 03 C7 57 00 10 -

Historical Log 1 status block recv

: :01 03 20 00 00 05 1E 00 00 05 1E 00 2C 00 00 06 08 17 51 08

00 06 08 18 4E 39 00 00 00 00 00 00 00 00 00 00 00

send

: :01 03 C3 4F 00 01 -

Log Retrieval header recv

: :01 03 02 FF FF 00 00

send

: :01 10 C3 4F 00 04 08 02 80 05 01 00 00 00 00 -

Engage the log recv

: :01 10 C3 4F 00 04

send

: :01 03 C7 57 00 10 -

Historical Log 1 status block recv

: :01 03 20 00 00 05 1E 00 00 05 1E 00 2C 00 02 06 08 17 51 08

00 06 08 18 4E 39 00 00 00 00 00 00 00 00 00 00 00

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 37

B: Modbus Map and Retrieving Logs

send

: :01 10 C3 51 00 02 04 00 00 00 00 -

Set the retrieval index recv

: :01 10 C3 51 00 02

send

: :01 03 C3 51 00 40 -

Read first half of window recv

: :01 03 80 00 00 00 00 06 08 17 51 08 00 00 19 00 2F 27 0F 00

00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 03

E8 00 01 00 05 00 00 00 00 00 00 06 08 17 51 09 00 00 19 00

2F 27 0F 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00

00 00 00 03 E8 00 01 00 04 00 00 00 00 00 00 06 08 17 51 0A

00 00 19 00 2F 27 0F 00 00 00 00 00 00 00 00 00 00 00 00 00

00 00 00 00 00 00 00 03 E8 00 00 00 00

send

: :01 03 C3 91 00 30 -

Read second half of window recv

: :01 03 60 00 05 00 00 00 00 00 00 06 08 17 51 0B 00 00 19 00

2F 27 0F 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00

00 00 00 03 E8 00 01 00 04 00 00 00 00 00 00 06 08 17 51 0C

00 00 19 00 2F 27 0F 00 00 00 00 00 00 00 00 00 00 00 00 00

00 00 00 00 00 00 00 03 E8 00 01 00 04 00 00 00 00 00 00 00

00

send

: :01 03 C3 51 00 40 -

Read first half of last window recv

: :01 03 80 00 00 05 19 06 08 18 4E 35 00 00 19 00 2F 27 0F 00

00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 03

E8 00 01 00 04 00 00 00 00 00 00 06 08 18 4E 36 00 00 19 00

2F 27 0F 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00

00 00 00 03 E8 00 01 00 04 00 00 00 00 00 00 06 08 18 4E 37

00 00 19 00 2F 27 0F 00 00 00 00 00 00 00 00 00 00 00 00 00

00 00 00 00 00 00 00 03 E8 00 00 00 00

send

: :01 03 C3 91 00 30 -

Read second half of last window recv

: :01 03 60 00 05 00 00 00 00 00 00 06 08 18 4E 38 00 00 19 00

2F 27 0F 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00

00 00 00 03 E8 00 01 00 04 00 00 00 00 00 00 06 08 18 4E 39

00 00 19 00 2F 27 0F 00 00 00 00 00 00 00 00 00 00 00 00 00

00 00 00 00 00 00 00 03 E8 00 00 00 05 00 00 00 00 00 00 00

00

send

: :01 06 C3 4F 00 00 -

Disengage the log recv

: :01 06 C3 4F 00 00

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 38

B: Modbus Map and Retrieving Logs

Sample Historical Log 1 Record:

Historical Log 1 Record and Programmable Settings

13|01|00 01|23 75|23 76|23 77|1F 3F 1F 40|1F 41

1F 42|1F 43 1F 44|06 0B 06 0C|06 0D 06 0E|17 75|

17 76|17 77|18 67|18 68|18 69|00 00 . . . . . .

62 62 62 34 34 34 44 44 62 62 62 62 62 62 . . .

These are the These are the These are the Descriptions:

Item Values: Type and Size:

13 - # registers

01

01

- # sectors

- interval

23 75 6 2 - (SINT 2 byte) Volts A THD Maximum

23 76 6 2 - (SINT 2 byte) Volts B THD Maximum

23 77 6 2 - (SINT 2 byte) Volts C THD Maximum

1F 3F 1F 40 3 4 - (Float 4 byte) Volts A Minimum

1F 41 1F 42 3 4 - (Float 4 byte) Volts B Minimum

1F 43 1F 44 3 4 - (Float 4 byte) Volts C Minimum

06 0B 06 0C 4 4 - (Energy 4 byte) VARhr Negative Phase A

06 0D 06 0E 4 4 - (Energy 4 byte) VARhr Negative Phase B

17 75 6 2 - (SINT 2 byte) Volts A 1 st

Harmonic

Magnitude

17 76 6 2 - (SINT 2 byte) Volts A 2 nd

Harmonic

Magnitude

17 77 6 2 - (SINT 2 byte) Volts A 3 rd

Harmonic

Magnitude

18 67 6 2 - (SINT 2 byte) Ib 3 rd

Harmonic Magnitude

18 68 6 2 - (SINT 2 byte) Ib 4 th

Harmonic Magnitude

18 69 6 2 - (SINT 2 byte) Ib 5 th

Harmonic Magnitude

Sample Record

06 08 17 51 08 00|00 19|00 2F|27 0F|00 00 00 00|00

00 00 00|00 00 00 00|00 00 00 00|00 00 00 00|03 E8|

00 01|00 05|00 00|00 00|00 00 . . .

11 08 17 51 08 00 - August 23, 2011 17:08:00

00 19 - 2.5%

00 2F - 4.7%

27 0F - 999.9% (indicates the value isn’t valid)

00 00 00 00 - 0

00 00 00 00 - 0

00 00 00 00 - 0

00 00 00 00 - 0

00 00 00 00 - 0

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 39

B: Modbus Map and Retrieving Logs

03 E8 - 100.0% (Fundamental)

00 01 - 0.1%

00 05 - 0.5%

00 00 - 0.0%

00 00 - 0.0%

00 00 - 0.0%

B.6: Important Note Concerning the Shark ® 200S Meter's Modbus

Map

In depicting Modbus Registers (Addresses), the Shark® 200S meter's Modbus map uses Holding Registers only.

B.6.1: Hex Representation

The representation shown in the table below is used by developers of Modbus drivers and libraries, SEL 2020/2030 programmers and Firmware Developers. The Shark ® meter's Modbus map also uses this representation.

Hex Description

0008 - 000F Meter Serial Number

B.6.2: Decimal Representation

The Shark ® meter's Modbus map defines Holding Registers as (4X) registers. Many popular SCADA and HMI packages and their Modbus drivers have user interfaces that require users to enter these Registers starting at 40001. So instead of entering two separate values, one for register type and one for the actual register, they have been combined into one number.

The Shark ® 200S meter's Modbus map uses a shorthand version to depict the decimal fields, i.e., not all of the digits required for entry into the SCADA package UI are shown. For example:

You need to display the meter's serial number in your SCADA application. The Shark®

200S meter's Modbus map shows the following information for meter serial number:

Decimal Description

9 - 16 Meter Serial Number

In order to retrieve the meter's serial number, enter 40009 into the SCADA UI as the starting register, and 8 as the number of registers.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 40

B: Modbus Map and Retrieving Logs

• In order to work with SCADA and Driver packages that use the 40001 to 49999 method for requesting holding registers, take 40000 and add the value of the register (Address) in the decimal column of the Modbus Map. Then enter the number

(e.g., 4009) into the UI as the starting register.

• For SCADA and Driver packages that use the 400001 to 465536 method for requesting holding registers take 400000 and add the value of the register

(Address) in the decimal column of the Modbus Map. Then enter the number (e.g.,

400009) into the UI as the starting register. The drivers for these packages strip off the leading four and subtract 1 from the remaining value. This final value is used as the starting register or register to be included when building the actual modbus message.

B.7: Modbus Register Map (MM-1 to MM-

23

)

The Shark® 200S meter's Modbus Register map begins on the following page.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 41

B: Modbus Map and Retrieving Logs

This page intentionally left blank.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 B - 42

B: Modbus Map and Retrieving Logs

Modbus Address

Hex Decimal

Identification Block

0000 0007

0008

0010

-

-

000F

0010

0011

0013

0014

0015

0016

0018

0019

001A

001E

0027

002F

0116

0131

01F4

0012

0013

0014

0015

0017

0018

0019

001D

0026

002E

0115

0130

01F3

0203

-

-

-

-

-

-

-

-

-

-

-

-

-

-

1 -

9 -

17 -

0126

0127

0128

0129

012A

012B

012C

012D

011C

011D

011E

011F

0120

0121

0122

0123

0124

0125

Readings Block ( Integer values)

0116

0117

-

-

0117

0118

0118

0119

011A

011B

-

-

-

-

0119

011A

011B

011C

-

-

-

-

-

-

-

-

-

-

011D

011E

011F

0120

0121

0122

0123

0124

0125

0126

-

-

-

-

-

-

-

-

0127

0128

0129

012A

012B

012C

012D

012E

280 -

281 -

282 -

283 -

284 -

285 -

286 -

287 -

288 -

289 -

290 -

291 -

292 -

293 -

294 -

295 -

296 -

297 -

298 -

299 -

300 -

301 -

302 -

303 -

18 -

20 -

21 -

22 -

23 -

25 -

26 -

27 -

31 -

40 -

48 -

279 -

306 -

501 -

Description (Note 1)

8 Meter Name

16 Meter Serial Number

17 Meter Type

19 Firmware Version

20 Map Version

21 Meter Configuration

22 ASIC Version

24 Boot Firmware Version

25 Reserved

26 Reserved

30 Meter Type Name

39 Reserved

47 Reserved

278 Reserved

305 Integer Readings Block occupies these registers, see below

500 Reserved

516 Reserved

280 Volts B-N

281 Volts C-N

282 Volts A-B

283 Volts B-C

284 Volts C-A

285 Amps A

286 Amps B

287 Amps C

288 Neutral Current

289 Watts, 3-Ph total

290 VARs, 3-Ph total

291 VAs, 3-Ph total

292 Power Factor, 3-Ph total

293 Frequency

294 Watts, Phase A

295 Watts, Phase B

296 Watts, Phase C

297 VARs, Phase A

298 VARs, Phase B

299 VARs, Phase C

300 VAs, Phase A

301 VAs, Phase B

302 VAs, Phase C

303 Power Factor, Phase A

Format Range (Note 6)

Fixed Data Section

ASCII 16 char

ASCII

UINT16

16 char bit-mapped

Units or Resolution

none none

------st -----vvv

ASCII

UINT16

UINT16

UINT16

ASCII

4 char

0 to 65535 bit-mapped

0-65535

4 char

ASCII 8 char none none

-----ccc --ffffff none none none

Comments read-only

t = 0 s= 1 vvv = V-switch:

V33 = standard 200S ccc = CT denominator (1 or 5), ffffff = calibration frequency (50 or 60)

Reserved

Reserved

Reserved

Reserved

Meter Data Section (Note 2)

SINT16

SINT16

SINT16

SINT16

UINT16

UINT16

UINT16

SINT16

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16

SINT16

SINT16

UINT16

SINT16

UINT16

SINT16

SINT16

0 to 9999

0 to 9999

0 to 9999

0 to 9999

0 to 9999

0 to 9999

0 to 9999

0 to 9999

-9999 to +9999

-9999 to +9999

-9999 to +9999

0 to +9999

-1000 to +1000

0 to 9999

-9999 M to +9999

-9999 M to +9999

-9999 M to +9999

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

0 to +9999

0 to +9999

0 to +9999

-1000 to +1000 amps amps amps watts

VARs

VAs none

Hz watts watts volts volts volts volts volts amps watts

VARs

VARs

VARs

VAs

VAs

VAs none

read-only

1.Use the settings from Programmable settings for scale and decimal point location. (see User Settings Flags)

2. Per phase power and PF have values only for WYE hookup and will be zero for all other hookups.

3. If the reading is 10000 that means that the value is out of range. Please adjust the programmable settings in that case. The display will also show '----' in case of over range.

# Reg

194

16

16

8

8

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

8

231

4

9

1

1

1

2

2

1

1

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-1

B: Modbus Map and Retrieving Logs

012E

012F

0130

Modbus Address

Hex Decimal

012F 304 -

0130 305 -

0130 305 - 305

Description (Note 1)

304 Power Factor, Phase B

305 Power Factor, Phase C

Power Factor, Phase C

0415

0417

0419

041B

041D

041F

0421

0423

0424

0425

0426

0427

0428

0403

0405

0407

0409

040B

040D

040F

0411

0413

Primary Readings Block

03E7

03E9

-

-

03E8

03EA

03EB

03ED

03EF

03F1

03F3

03F5

03F7

03F9

03FB

03FD

03FF

0401

-

-

-

-

-

-

-

-

-

-

-

-

03EC

03EE

03F0

03F2

03F4

03F6

03F8

03FA

03FC

03FE

0400

0402

-

-

-

-

-

-

-

-

-

0404

0406

0408

040A

040C

040E

0410

0412

0414

-

-

-

-

-

-

-

-

-

-

-

-

-

0416

0418

041A

041C

041E

0420

0422

0423

0424

0425

0426

0427

0428

1000 -

1002 -

1004 -

1006 -

1008 -

1010 -

1012 -

1014 -

1016 -

1018 -

1020 -

1022 -

1024 -

1026 -

1028 -

1030 -

1032 -

1034 -

1036 -

1038 -

1040 -

1042 -

1044 -

1046 -

1048 -

1050 -

1052 -

1054 -

1056 -

1058 -

1060 -

1061 -

1062 -

1063 -

1064 -

1065 -

1001 Volts A-N

1003 Volts B-N

1005 Volts C-N

1007 Volts A-B

1009 Volts B-C

1011 Volts C-A

1013 Amps A

1015 Amps B

1017 Amps C

1019 Watts, 3-Ph total

1021 VARs, 3-Ph total

1023 VAs, 3-Ph total

1025 Power Factor, 3-Ph total

1027 Frequency

1029 Neutral Current

1031 Watts, Phase A

1033 Watts, Phase B

1035 Watts, Phase C

1037 VARs, Phase A

1039 VARs, Phase B

1041 VARs, Phase C

1043 VAs, Phase A

1045 VAs, Phase B

1047 VAs, Phase C

1049 Power Factor, Phase A

1051 Power Factor, Phase B

1053 Power Factor, Phase C

1055 Symmetrical Component Magnitude, 0 Seq

1057 Symmetrical Component Magnitude, + Seq

1059 Symmetrical Component Magnitude, - Seq

1060 Symmetrical Component Phase, 0 Seq

1061 Symmetrical Component Phase, + Seq

1062 Symmetrical Component Phase, - Seq

1063 Unbalance, 0 sequence component

1064 Unbalance, -sequence component

1065 Current Unbalance

Format

SINT16

SINT16

Range (Note 6)

-1000 to +1000

-1000 to +1000

SINT16 -1000 to +1000

Units or Resolution

none none none

`

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

SINT16

SINT16

SINT16

UINT16

UINT16

UINT16

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

0 to 9999 M

0 to 9999 M

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

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

0 to 9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-1.00 to +1.00

0 to 65.00

0 to 9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-1.00 to +1.00

-1.00 to +1.00

-1.00 to +1.00

0 to 9999 M

0 to 9999 M

0 to 9999 M

-1800 to +1800

-1800 to +1800

-1800 to +1800

0 to 10000

0 to 10000

0 to 20000 amps watts watts watts

VARs

VARs

VARs

VAs

VAs volts volts volts volts volts volts amps amps amps watts

VARs

VAs none

Hz

VAs none none none volts volts volts

0.1 degree

0.1 degree

0.1 degree

0.01%

0.01%

0.01%

read-only

Comments

Per phase power and PF have values only for WYE hookup and will be zero for all other hookups.

Voltage unbalance per IEC6100-4.30

Values apply only to WYE hookup and will be zero for all other hookups.

Block Size:

# Reg

1

1

1

27

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

1

1

2

1

1

1

66

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-2

B: Modbus Map and Retrieving Logs

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

05F1

05F3

05F5

05F7

05F9

05FB

0613

0615

0617

0619

061B

061D

061F

0621

0623

0625

0627

0629

062B

05FD

05FF

0601

0603

0605

0607

0609

060B

060D

060F

0611

05DF

05E1

05E3

05E5

05E7

05E9

05EB

05ED

05EF

Modbus Address

Hex Decimal

Primary Energy Block

05DB 05DC 1500 -

Description (Note 1)

1501 W-hours, Received

05DD 05DE 1502 1503 W-hours, Delivered

05E0

05E2

05E4

05E6

05E8

05EA

05EC

05EE

05F0

-

-

-

-

-

-

-

-

-

1504 -

1506 -

1508 -

1510 -

1512 -

1514 -

1516 -

1518 -

1520 -

1505 W-hours, Net

1507 W-hours, Total

1509 VAR-hours, Positive

1511 VAR-hours, Negative

1513 VAR-hours, Net

1515 VAR-hours, Total

1517 VA-hours, Total

1519 W-hours, Received, Phase A

1521 W-hours, Received, Phase B

05F2

05F4

05F6

05F8

05FA

05FC

0614

0616

0618

061A

061C

061E

0620

0622

0624

0626

0628

062A

062C

05FE

0600

0602

0604

0606

0608

060A

060C

060E

0610

0612

1522 -

1524 -

1526 -

1528 -

1530 -

1532 -

1556 -

1558 -

1560 -

1562 -

1564 -

1566 -

1568 -

1570 -

1572 -

1574 -

1576 -

1578 -

1580 -

1534 -

1536 -

1538 -

1540 -

1542 -

1544 -

1546 -

1548 -

1550 -

1552 -

1554 -

1523 W-hours, Received, Phase C

1525 W-hours, Delivered, Phase A

1527 W-hours, Delivered, Phase B

1529 W-hours, Delivered, Phase C

1531 W-hours, Net, Phase A

1533 W-hours, Net, Phase B

1535 W-hours, Net, Phase C

1537 W-hours, Total, Phase A

1539 W-hours, Total, Phase B

1541 W-hours, Total, Phase C

1543 VAR-hours, Positive, Phase A

1545 VAR-hours, Positive, Phase B

1547 VAR-hours, Positive, Phase C

1549 VAR-hours, Negative, Phase A

1551 VAR-hours, Negative, Phase B

1553 VAR-hours, Negative, Phase C

1555 VAR-hours, Net, Phase A

1557 VAR-hours, Net, Phase B

1559 VAR-hours, Net, Phase C

1561 VAR-hours, Total, Phase A

1563 VAR-hours, Total, Phase B

1565 VAR-hours, Total, Phase C

1567 VA-hours, Phase A

1569 VA-hours, Phase B

1571 VA-hours, Phase C

1573 W-hours, Received, rollover count

1575 W-hours, Delivered, rollover count

1577 VAR-hours, Positive, rollover count

1579 VAR-hours, Negative, rollover count

1581 VA-hours, rollover count

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

UINT32

UINT32

UINT32

UINT32

UINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

Format Range (Note 6)

SINT32

SINT32

SINT32

Units or Resolution

0 to 99999999 or

0 to -99999999

0 to 99999999 or

0 to -99999999

Wh per energy format

Wh per energy format

-99999999 to 99999999 Wh per energy format

Comments read-only

* Wh received & delivered always have opposite signs

* Wh received is positive for "view as load", delivered is positive for "view as generator"

* 5 to 8 digits

SINT32

SINT32

SINT32

SINT32

0 to 99999999

0 to 99999999

Wh per energy format

VARh per energy format

0 to -99999999 VARh per energy format

-99999999 to 99999999 VARh per energy format

* decimal point implied, per energy format

* resolution of digit before decimal point = units, kilo, or mega, per energy format

# Reg

2

2

2

2

2

2

2

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

0 to 99999999

0 to 99999999

VARh per energy format

VAh per energy format

0 to 99999999 or

0 to -99999999

0 to 99999999 or

0 to -99999999

0 to 99999999 or

0 to -99999999

0 to 99999999 or

0 to -99999999

0 to 99999999 or

0 to -99999999

Wh per energy format

Wh per energy format

Wh per energy format

Wh per energy format

Wh per energy format

0 to 99999999 or

0 to -99999999

Wh per energy format

-99999999 to 99999999 Wh per energy format

-99999999 to 99999999 Wh per energy format

-99999999 to 99999999 Wh per energy format

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to -99999999

0 to -99999999

Wh per energy format

Wh per energy format

Wh per energy format

VARh per energy format

VARh per energy format

VARh per energy format

VARh per energy format

VARh per energy format

0 to -99999999 VARh per energy format

-99999999 to 99999999 VARh per energy format

-99999999 to 99999999 VARh per energy format

-99999999 to 99999999 VARh per energy format

0 to 99999999 VARh per energy format

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 4,294,967,294

0 to 4,294,967,294

0 to 4,294,967,294

0 to 4,294,967,294

0 to 4,294,967,294

VARh per energy format

VARh per energy format

VAh per energy format

VAh per energy format

VAh per energy format

* see note 10

These registers count the number of times their corresponding energy accumulators have wrapped from

+max to 0. They are reset when energy is reset.

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-3

B: Modbus Map and Retrieving Logs

062D

062F

0631

0633

0635

0637

0639

063B

063D

063F

0641

-

-

-

063E

0640

0642

07E3

07E5

07E7

07E9

07EB

07ED

07EF

07F1

07F3

07F5

0643

0645

0647

0649

064B

063D

064F

0651

0653

-

-

-

-

-

-

-

-

-

0644

0646

0648

064A

064C

064E

0650

0652

0654

Primary Demand Block

07CF

07D1

07D3

07D5

07D7

-

-

-

-

-

07D0

07D2

07D4

07D6

07D8

07D9

07DB

07DD

07DF

07E1

-

-

-

-

-

07DA

07DC

07DE

07E0

07E2

-

-

-

-

-

-

-

-

-

-

07E4

07E6

07E8

07EA

07EC

07EE

07F0

07F2

07F4

07F6

-

-

-

-

-

-

-

Modbus Address

Hex Decimal

062E 1582 -

Description (Note 1)

1583 W-hours in the Interval, Received

0630

0632

0634

0636

0638

063A

063C

1584 -

1586 -

1588 -

1590 -

1592 -

1594 -

1596 -

1585 W-hours in the Interval, Delivered

1587 VAR-hours in the Interval, Positive

1589 VAR-hours in the Interval, Negative

1591 VA-hours in the Interval, Total

1593 W-hours in the Interval, Received, Phase A

1595 W-hours in the Interval, Received, Phase B

1597 W-hours in the Interval, Received, Phase C

2000 -

2002 -

2004 -

2006 -

2008 -

2010 -

2012 -

2014 -

2016 -

2018 -

2020 -

2022 -

2024 -

2026 -

2028 -

2030 -

2032 -

2034 -

2036 -

2038 -

1598 -

1600 -

1602 -

1599 W-hours in the Interval, Delivered, Phase A

1601 W-hours in the Interval, Delivered, Phase B

1603 W-hours in the Interval, Delivered, Phase C

1604 -

1606 -

1608 -

1610 -

1612 -

1614 -

1616 -

1618 -

1620 -

1605 VAR-hours in the Interval, Positive, Phase A

1607 VAR-hours in the Interval, Positive, Phase B

1609 VAR-hours in the Interval, Positive, Phase C

1611 VAR-hours in the Interval, Negative, Phase A

1613 VAR-hours in the Interval, Negative, Phase B

1615 VAR-hours in the Interval, Negative, Phase C

1617 VA-hours in the Interval, Phase A

1619 VA-hours in the Interval, Phase B

1621 VA-hours in the Interval, Phase C

2001 Amps A, Average

2003 Amps B, Average

2005 Amps C, Average

2007 Positive Watts, 3-Ph, Average

2009 Positive VARs, 3-Ph, Average

2011 Negative Watts, 3-Ph, Average

2013 Negative VARs, 3-Ph, Average

2015 VAs, 3-Ph, Average

2017 Positive PF, 3-Ph, Average

2019 Negative PF, 3-PF, Average

2021 Neutral Current, Average

2023 Positive Watts, Phase A, Average

2025 Positive Watts, Phase B, Average

2027 Positive Watts, Phase C, Average

2029 Positive VARs, Phase A, Average

2031 Positive VARs, Phase B, Average

2033 Positive VARs, Phase C, Average

2035 Negative Watts, Phase A, Average

2037 Negative Watts, Phase B, Average

2039 Negative Watts, Phase C, Average

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

Format

SINT32

SINT32

Range (Note 6)

0 to 99999999 or

0 to -99999999

0 to 99999999 or

0 to -99999999

0 to 99999999 SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

0 to -99999999

0 to 99999999

0 to 99999999 or

0 to -99999999

0 to 99999999 or

0 to -99999999

0 to 99999999 or

0 to -99999999

0 to 99999999 or

0 to -99999999

0 to 99999999 or

0 to -99999999

0 to 99999999 or

0 to -99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to -99999999

0 to -99999999

0 to -99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 9999 M

0 to 9999 M

0 to 9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-1.00 to +1.00

-1.00 to +1.00

0 to 9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

Units or Resolution

Wh per energy format

Wh per energy format

VARh per energy format

VARh per energy format

VAh per energy format

Wh per energy format

Wh per energy format

Wh per energy format

Wh per energy format

Wh per energy format

Wh per energy format watts

VARs

VAs none none amps watts watts watts

VARs

VARs

VARs watts watts watts

VARh per energy format

VARh per energy format

VARh per energy format

VARh per energy format

VARh per energy format

VARh per energy format

VAh per energy format

VAh per energy format

VAh per energy format amps amps amps watts

VARs

Comments

* Wh received & delivered always have opposite signs

* Wh received is positive for "view as load" , delivered is positive for "view as generator"

* 5 to 8 digits

* decimal point implied, per energy format

* resolution of digit before decimal point = u

read-only

Block Size:

# Reg

122

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-4

B: Modbus Map and Retrieving Logs

0BDB

0BDD

0BDF

0BE1

0BE3

0BE5

0BE7

0BE9

0BEB

0BED

0BEF

0BF1

0BF3

0BF5

07F7

07F9

07FB

07FD

07FF

0801

0803

0805

0807

0809

080B

080D

-

-

-

-

-

-

-

-

-

-

-

Modbus Address

Hex Decimal

07F8 2040 -

Description (Note 1)

2041 Negative VARs, Phase A, Average

07FA

07FC

07FE

0800

0802

0804

0806

0808

080A

080C

080E

2042 -

2044 -

2046 -

2048 -

2050 -

2052 -

2054 -

2056 -

2058 -

2060 -

2062 -

2043 Negative VARs, Phase B, Average

2045 Negative VARs, Phase C, Average

2047 VAs, Phase A, Average

2049 VAs, Phase B, Average

2051 VAs, Phase C, Average

2053 Positive PF, Phase A, Average

2055 Positive PF, Phase B, Average

2057 Positive PF, Phase C, Average

2059 Negative PF, Phase A, Average

2061 Negative PF, Phase B, Average

2063 Negative PF, Phase C, Average

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

Uncompensated Readings Block

0BB7

0BB9

0BBB

0BBD

0BBF

0BC1

0BC3

0BC5

OBC7

0BC9

0BCB

0BCD

0BCF

0BD1

0BD3

0BD5

0BD7

0BB8

0BBA

0BBC

0BBE

0BC0

0BC2

0BC4

0BC6

0BC8

0BCA

0BCC

0BCE

0BD0

0BD2

0BD4

0BD6

0BD8

3000 -

3002 -

3004 -

3006 -

3008 -

3010 -

3012 -

3014 -

3016 -

3018 -

3020 -

3022 -

3024 -

3026 -

3028 -

3030 -

3032 -

3001 Watts, 3-Ph total

3003 VARs, 3-Ph total

3005 VAs, 3-Ph total

3007 Power Factor, 3-Ph total

3009 Watts, Phase A

3011 Watts, Phase B

3013 Watts, Phase C

3015 VARs, Phase A

3017 VARs, Phase B

3019 VARs, Phase C

3021 VAs, Phase A

3023 VAs, Phase B

3025 VAs, Phase C

3027 Power Factor, Phase A

3029 Power Factor, Phase B

3031 Power Factor, Phase C

3033 W-hours, Received

0BD9 0BDA 3034 3035 W-hours, Delivered

-

-

-

-

-

-

-

-

-

-

-

-

-

-

0BDC

0BDE

0BE0

0BE2

0BE4

0BE6

0BE8

0BEA

0BEC

0BEE

0BF0

0BF2

0BF4

0BF6

3036 -

3038 -

3040 -

3042 -

3044 -

3046 -

3048 -

3050 -

3052 -

3054 -

3056 -

3058 -

3060 -

3062 -

3037 W-hours, Net

3039 W-hours, Total

3041 VAR-hours, Positive

3043 VAR-hours, Negative

3045 VAR-hours, Net

3047 VAR-hours, Total

3049 VA-hours, Total

3051 W-hours, Received, Phase A

3053 W-hours, Received, Phase B

3055 W-hours, Received, Phase C

3057 W-hours, Delivered, Phase A

3059 W-hours, Delivered, Phase B

3061 W-hours, Delivered, Phase C

3063 W-hours, Net, Phase A

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

Format

FLOAT

Range (Note 6)

-9999 M to +9999 M

Units or Resolution

VARs

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-1.00 to +1.00

-1.00 to +1.00

-1.00 to +1.00

-1.00 to +1.00

-1.00 to +1.00

-1.00 to +1.00

VARs

VARs

VAs

VAs

VAs none none none none none none

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

SINT32

SINT32

SINT32

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-1.00 to +1.00

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M watts

VARs

VAs none watts watts watts

VARs

VARs

VARs

VAs

VAs

-9999 M to +9999 M

-1.00 to +1.00

-1.00 to +1.00

-1.00 to +1.00

VAs none none none

0 to 99999999 or

0 to -99999999

0 to 99999999 or

Wh per energy format

Wh per energy format

0 to -99999999

-99999999 to 99999999 Wh per energy format

0 to 99999999

0 to 99999999

Wh per energy format

VARh per energy format

0 to -99999999 VARh per energy format

-99999999 to 99999999 VARh per energy format

0 to 99999999

0 to 99999999

0 to 99999999 or

0 to 99999999 or

VARh per energy format

VAh per energy format

Wh per energy format

Wh per energy format

0 to 99999999 or

99999999

Wh per energy format

0 to 99999999 or

99999999

Wh per energy format

Wh per energy format

Wh per energy format

-99999999 to 99999999 Wh per energy format

read-only

Comments

Per phase power and PF have values only for WYE hookup and will be zero for all other hookups.

* Wh received & delivered always have opposite signs

* Wh received is positive for "view as load", delivered is positive for "view as generator"

* 5 to 8 digits

* decimal point implied, per energy format

* resolution of digit before decimal point = units, kilo, or mega, per energy format

* see note 10

# Reg

2

2

2

64

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-5

B: Modbus Map and Retrieving Logs

0BF7

0BF9

0BFB

0BFD

0BFF

0C01

0C03

0C05

0C07

0C09

0C0B

0C0D

0C0F

0C11

0C13

0C15

0C17

0C19

0C1B

0C1D

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

Modbus Address

Hex Decimal

0BF8 3064 -

Description (Note 1)

3065 W-hours, Net, Phase B

0BFA

0BFC

0BFE

0C00

0C02

0C04

0C06

0C08

0C0A

0C0C

0C0E

0C10

0C12

0C14

0C16

0C18

0C1A

0C1C

0C1E

3066 -

3068 -

3070 -

3072 -

3074 -

3076 -

3078 -

3080 -

3082 -

3084 -

3086 -

3088 -

3090 -

3092 -

3094 -

3096 -

3098 -

3100 -

3102 -

3067 W-hours, Net, Phase C

3069 W-hours, Total, Phase A

3071 W-hours, Total, Phase B

3073 W-hours, Total, Phase C

3075 VAR-hours, Positive, Phase A

3077 VAR-hours, Positive, Phase B

3079 VAR-hours, Positive, Phase C

3081 VAR-hours, Negative, Phase A

3083 VAR-hours, Negative, Phase B

3085 VAR-hours, Negative, Phase C

3087 VAR-hours, Net, Phase A

3089 VAR-hours, Net, Phase B

3091 VAR-hours, Net, Phase C

3093 VAR-hours, Total, Phase A

3095 VAR-hours, Total, Phase B

3097 VAR-hours, Total, Phase C

3099 VA-hours, Phase A

3101 VA-hours, Phase B

3103 VA-hours, Phase C

Phase Angle Block

1003

1004

1005

1006

1007

-

-

-

-

-

1003

1004

1005

1006

1007

1008 1008

4100 -

4101 -

4102 -

4103 -

4104 -

4105 -

4100 Phase A Current

4101 Phase B Current

4102 Phase C Current

4103 Angle, Volts A-B

4104 Angle, Volts B-C

4105 Angle, Volts C-A

Format

SINT32

Range (Note 6) Units or Resolution

-99999999 to 99999999 Wh per energy format

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

-99999999 to 99999999 Wh per energy format

0 to 99999999 Wh per energy format

0 to 99999999

0 to 99999999

Wh per energy format

Wh per energy format

0 to 99999999

0 to 99999999

0 to 99999999

VARh per energy format

VARh per energy format

VARh per energy format

0 to -99999999

0 to -99999999

VARh per energy format

VARh per energy format

0 to -99999999 VARh per energy format

-99999999 to 99999999 VARh per energy format

-99999999 to 99999999 VARh per energy format

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

SINT32

-99999999 to 99999999 VARh per energy format

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

VARh per energy format

VARh per energy format

VARh per energy format

VAh per energy format

SINT16

SINT16

SINT16

SINT16

SINT16

-1800 to +1800

-1800 to +1800

-1800 to +1800

-1800 to +1800

-1800 to +1800

VAh per energy format

VAh per energy format

0.1 degree

0.1 degree

0.1 degree

0.1 degree

0.1 degree

SINT16 -1800 to +1800 0.1 degree

read-only

Comments # Reg

2

2

2

104

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

1

1

1

1

1

1

6

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-6

B: Modbus Map and Retrieving Logs

Modbus Address

Hex Decimal

Status Block

1193 1193 4500 4500 Port ID

Description (Note 1)

1194 1194 4501 4501 Meter Status

Format Range (Note 6)

UINT16 1 to 4

UINT16 bit-mapped

Units or Resolution

none mmmpch-- tffeeccc

Comments read-only

Identifies which Shark COM port a master is connected to; 1 for COM1, 2 for COM2, etc.

mmm = measurement state (0=off, 1=running normally,

2=limp mode, 3=warmup, 6&7=boot, others unused) See note 16. pch = NVMEM block OK flags (p=profile, c=calibration, h=header), flag is 1 if OK t - CT PT compensation status. (0=Disabled,1=Enabled) ff = flash state (0=initializing, 1=logging disabled by

Vswitch, 3=logging) ee = edit state (0=startup, 1=normal, 2=privileged command session, 3=profile update mode) ccc = port enabled for edit(0=none, 1-4=COM1-COM4,

7=front panel)

# Reg

1

1

1195

1196

1198

119B

119E

1195

-

-

-

-

1197

119A

119D

119E

4502 -

4503 -

4505 -

4508 -

4511 -

4502 Limits Status

4504 Time Since Reset

4507 Meter On Time

4510 Current Date and Time

4511 Clock Sync Status

UINT16 bit-mapped

UINT32 0 to 4294967294 4 msec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

UINT16 bit-mapped mmmp pppe 0000 000s

119F

1F29

1F2B

1F2D

1F2F

1F31

1F33

1F35

1F37

1F39

1F3B

1F3D

-

-

-

-

-

-

-

-

-

-

-

-

119F

Short term Primary Minimum Block

1F27 1F28 7976 -

1F2A

1F2C

1F2E

1F30

1F32

1F34

1F36

1F38

1F3A

1F3C

1F3E

Primary Minimum Block

1F3F

1F41

1F43

-

-

1F40

1F42

1F44 e

El I d

4512 -

7978 -

7980 -

7982 -

7984 -

7986 -

7988 -

7990 -

7992 -

7994 -

7996 -

7998 -

8000 -

8002 -

8004 -

i /G

4512 Current Day of Week UINT16 1 to 7

0 to 9999 M 7977 Volts A-N, previous Demand interval Short Term

Minimum

7979 Volts B-N, previous Demand interval Short Term

Minimum

7981 Volts C-N, previous Demand interval Short Term

Minimum

7983 Volts A-B, previous Demand interval Short Term

Minimum

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT 7985 Volts B-C, previous Demand interval Short Term

Minimum

7987 Volts C-A, previous Demand interval Short Term

Minimum

7989 Volts A-N, Short Term Minimum

FLOAT

FLOAT

7991 Volts B-N, Short Term Minimum

7993 Volts C-N, Short Term Minimum

FLOAT

FLOAT

7995 Volts A-B, Short Term Minimum

7997 Volts B-C, Short Term Minimum

7999 Volts C-A, Short Term Minimum

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

0 to 9999 M

0 to 9999 M

0 to 9999 M

0 to 9999 M

0 to 9999 M

8001 Volts A-N, Minimum

8003 Volts B-N, Minimum

8005 Volts C-N, Minimum

FLOAT

FLOAT

FLOAT

0 to 9999 M

0 to 9999 M

0 to 9999 M

T h

87654321 87654321

1 day volts volts volts volts volts volts volts volts volts volts volts volts volts volts volts high byte is setpt 1, 0=in, 1=out low byte is setpt 2, 0=in, 1=out see notes 11, 12, 17 wraps around after max count mmmp pppe = configuration per programmable settings

(see register 30011, 0x753A) s = status: 1=working properly, 0=not working

1=Sun, 2=Mon, etc.

read-only

1

1

13

2

3

3

1

Minimum instantaneous value measured during the demand interval before the one most recently completed.

Minimum instantaneous value measured during the most recently completed demand interval.

2

2

2

2

2

2

2

2

2

2

2

2

24

read-only

2

2

2

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-7

B: Modbus Map and Retrieving Logs

1F73

1F75

1F77

1F79

1F87

1F89

1F8B

1F8D

1F8E

1F8F

1F90

1F91

1F92

1F93

1F7B

1F7D

1F7F

1F81

1F83

1F85

1F5D

1F5F

1F61

1F63

1F65

1F67

1F69

1F6B

1F6D

1F6F

1F71

1F45

1F47

1F49

1F4B

1F4D

1F4F

1F51

1F53

1F55

1F57

1F59

1F5B

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

1F7A

1F88

1F8A

1F8C

1F8D

1F8E

1F8F

1F90

1F91

1F92

1F94

1F7C

1F7E

1F80

1F82

1F84

1F86

-

-

-

-

-

-

-

-

-

-

Modbus Address

Hex Decimal

1F46 8006 -

Description (Note 1)

8007 Volts A-B, Minimum

1F48 8008 8009 Volts B-C, Minimum

-

-

-

-

-

-

-

-

-

-

-

-

-

1F5E

1F60

1F62

1F64

1F66

1F68

1F6A

1F6C

1F6E

1F70

1F4A

1F4C

1F4E

1F50

1F52

1F54

1F56

1F58

1F5A

1F5C

1F72

1F74

1F76

8032 -

8034 -

8036 -

8038 -

8040 -

8042 -

8044 -

8046 -

8048 -

8010 -

8012 -

8014 -

8016 -

8018 -

8020 -

8022 -

8024 -

8026 -

8028 -

8030 -

8050 -

8052 -

8054 -

Format

FLOAT

FLOAT

8011 Volts C-A, Minimum

8013 Amps A, Minimum Avg Demand

8015 Amps B, Minimum Avg Demand

8017 Amps C, Minimum Avg Demand

8019 Positive Watts, 3-Ph, Minimum Avg Demand

8021 Positive VARs, 3-Ph, Minimum Avg Demand

8023 Negative Watts, 3-Ph, Minimum Avg Demand

8025 Negative VARs, 3-Ph, Minimum Avg Demand

8027 VAs, 3-Ph, Minimum Avg Demand

8029 Positive Power Factor, 3-Ph, Minimum Avg

Demand

8031 Negative Power Factor, 3-Ph, Minimum Avg

Demand

8033 Frequency, Minimum

FLOAT

FLOAT

FLOAT

8035 Neutral Current, Minimum Avg Demand

FLOAT

FLOAT

8037 Positive Watts, Phase A, Minimum Avg Demand FLOAT

8039 Positive Watts, Phase B, Minimum Avg Demand FLOAT

8041 Positive Watts, Phase C, Minimum Avg Demand FLOAT

8043 Positive VARs, Phase A, Minimum Avg Demand FLOAT

8045 Positive VARs, Phase B, Minimum Avg Demand FLOAT

8047 Positive VARs, Phase C, Minimum Avg Demand FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

8049 Negative Watts, Phase A, Minimum Avg

Demand

8051 Negative Watts, Phase B, Minimum Avg

Demand

FLOAT

FLOAT

8053 Negative Watts, Phase C, Minimum Avg

Demand

FLOAT

8055 Negative VARs, Phase A, Minimum Avg Demand FLOAT

Range (Note 6)

0 to 9999 M

0 to 9999 M

0 to 9999 M

0 to 9999 M

0 to 9999 M

0 to 9999 M

0 to +9999 M

0 to +9999 M

0 to +9999 M

0 to +9999 M

-9999 M to +9999 M

-1.00 to +1.00

-1.00 to +1.00

0 to 65.00

0 to 9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M none

Hz amps watts watts watts

VARs

VARs

VARs watts watts watts

VARs

Units or Resolution

volts volts volts amps amps amps watts

VARs watts

VARs

VAs none

1F78 8056 8057 Negative VARs, Phase B, Minimum Avg Demand FLOAT -9999 M to +9999 M VARs

8058 -

8060 -

8062 -

8064 -

8066 -

8068 -

8070 -

8072 -

8074 -

8076 -

8078 -

8079 -

8080 -

8081 -

8082 -

8083 -

8084 -

8059 Negative VARs, Phase C, Minimum Avg

Demand

8061 VAs, Phase A, Minimum Avg Demand

8063 VAs, Phase B, Minimum Avg Demand

8065 VAs, Phase C, Minimum Avg Demand

8067 Positive PF, Phase A, Minimum Avg Demand

8069 Positive PF, Phase B, Minimum Avg Demand

8071 Positive PF, Phase C, Minimum Avg Demand

8073 Negative PF, Phase A, Minimum Avg Demand

8075 Negative PF, Phase B, Minimum Avg Demand

8077 Negative PF, Phase C, Minimum Avg Demand

8078 Reserved

8079 Reserved

8080 Reserved

8081 Reserved

8082 Reserved

8083 Reserved

8085 Symmetrical Component Magnitude, 0 Seq,

Minimum

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-1.00 to +1.00

-1.00 to +1.00

-1.00 to +1.00

-1.00 to +1.00

-1.00 to +1.00

-1.00 to +1.00

0 to 9999 M

VARs

VAs

VAs

VAs none none none none none none volts

Comments

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-8

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

1

1

1

1

1

2

2

1

2

2

2

2

2

2

2

2

# Reg

2

2

2

2

2

2

2

2

2

2

2

2

B: Modbus Map and Retrieving Logs

20CF

20D2

20D5

20D8

20DB

20DE

20E1

20E4

20E7

20EA

1F95

1F97

1F99

1F9A

1F9B

1F9C

1F9D

1F9E

-

-

-

Modbus Address

Hex Decimal

1F96 8086 -

-

-

-

-

1F98

1F99

1F9A

1F9B

8088 -

8090 -

8091 -

8092 -

Description (Note 1)

8087 Symmetrical Component Magnitude, + Seq,

Minimum

8089 Symmetrical Component Magnitude, - Seq,

Minimum

8090 Symmetrical Component Phase, 0 Seq,

Minimum

8091 Symmetrical Component Phase, + Seq,

Format

FLOAT

FLOAT

SINT16

SINT16

8092 Symmetrical Component Phase, - Seq, Minimum SINT16

1F9C

1F9D

1F9E

8093 -

8094 -

8095 -

Primary Minimum Timestamp Block

8093 Unbalance, 0 sequence, Minimum

8094 Unbalance, -sequence, Minimum

8095 Current Unbalance, Minimum

Range (Note 6)

0 to 9999 M

0 to 9999 M

-1800 to +1800

UINT16

UINT16

UINT16

-1800 to +1800

-1800 to +1800

0 to 10000

0 to 10000

0 to 20000

-

-

-

-

-

-

-

-

-

-

20D1

20D4

20D7

20DA

20DD

20E0

20E3

20E6

20E9

20EC

8400 -

8403 -

8406 -

8409 -

8412 -

8415 -

8418 -

8421 -

8424 -

8427 -

8402 Volts A-N, Min Timestamp

8405 Volts B-N, Min Timestamp

8408 Volts C-N, Min Timestamp

8411 Volts A-B, Min Timestamp

8414 Volts B-C, Min Timestamp

8417 Volts C-A, Min Timestamp

8420 Amps A, Min Avg Dmd Timestamp

8423 Amps B, Min Avg Dmd Timestamp

8426 Amps C, Min Avg Dmd Timestamp

8429 Positive Watts, 3-Ph, Min Avg Dmd Timestamp

Units or Resolution

volts volts

0.1 degree

0.1 degree

0.1 degree

0.01%

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

0.01%

0.01%

read-only

20ED

20F0

20F3

-

-

-

20EF

20F2

20F5

8430 -

8433 -

8436 -

8432 Positive VARs, 3-Ph, Min Avg Dmd Timestamp TSTAMP 1Jan2000 - 31Dec2099 1 sec

8435 Negative Watts, 3-Ph, Min Avg Dmd Timestamp TSTAMP 1Jan2000 - 31Dec2099 1 sec

8438 Negative VARs, 3-Ph, Min Avg Dmd Timestamp TSTAMP 1Jan2000 - 31Dec2099 1 sec

20F6

20F9

20FC

20FF

2102

2105

2108

210B

210E

2111

2114

2117

211A

211D

2120

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

20F8

20FB

20FE

2101

2104

2107

210A

210D

2110

2113

2116

2119

211C

211F

2122

8439 -

8442 -

8445 -

8448 -

8451 -

8454 -

8457 -

8460 -

8463 -

8466 -

8469 -

8472 -

8475 -

8478 -

8481 -

8441 VAs, 3-Ph, Min Avg Dmd Timestamp

8444 Positive Power Factor, 3-Ph, Min Avg Dmd

Timestamp

8447 Negative Power Factor, 3-Ph, Min Avg Dmd

Timestamp

8450 Frequency, Min Timestamp

8453 Neutral Current, Min Avg Dmd Timestamp

8456 Positive Watts, Phase A, Min Avg Dmd

Timestamp

8459 Positive Watts, Phase B, Min Avg Dmd

Timestamp

8462 Positive Watts, Phase C, Min Avg Dmd

Timestamp

8465 Positive VARs, Phase A, Min Avg Dmd

Timestamp

8468 Positive VARs, Phase B, Min Avg Dmd

Timestamp

8471 Positive VARs, Phase C, Min Avg Dmd

Timestamp

8474 Negative Watts, Phase A, Min Avg Dmd

Timestamp

8477 Negative Watts, Phase B, Min Avg Dmd

Timestamp

8480 Negative Watts, Phase C, Min Avg Dmd

Timestamp

8483 Negative VARs, Phase A, Min Avg Dmd

Timestamp

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2100 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

Comments

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-9

# Reg

2

2

1

1

96

1

1

1

1

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

B: Modbus Map and Retrieving Logs

2129

212C

212F

2132

2135

2138

213B

213E

2141

2144

2147

214A

214D

2150

2153

2156

2123

2126

2159

215C

215F

2162

2165

2168

2171

2174

2311

2313

2315

2317

2319

-

-

-

-

-

-

-

-

-

-

-

-

-

-

Modbus Address

Hex Decimal

2125 8484 -

-

-

2128

212B

8487 -

8490 -

Description (Note 1)

8486 Negative VARs, Phase B, Min Avg Dmd

Timestamp

8489 Negative VARs, Phase C, Min Avg Dmd

Timestamp

8492 VAs, Phase A, Min Avg Dmd Timestamp

-

-

-

212E

2131

2134

8493 -

8496 -

8499 -

Format Range (Note 6) Units or Resolution

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

8495 VAs, Phase B, Min Avg Dmd Timestamp

8498 VAs, Phase C, Min Avg Dmd Timestamp

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

8501 Positive PF, Phase A, Min Avg Dmd Timestamp TSTAMP 1Jan2000 - 31Dec2099 1 sec

2137 8502 8504 Positive PF, Phase B, Min Avg Dmd Timestamp TSTAMP 1Jan2000 - 31Dec2099 1 sec

-

-

-

-

-

Short term Primary Maximum Block

230F 2310 8976 -

-

-

-

-

-

213A

213D

2140

2143

2146

2149

214C

214F

2152

2155

2158

215B

215E

2161

2164

2167

2170

2173

2176

2312

2314

2316

2318

231A

8505 -

8508 -

8511 -

8514 -

8517 -

8520 -

8523 -

8526 -

8529 -

8532 -

8535 -

8538 -

8541 -

8544 -

8547 -

8550 -

8553 -

8556 -

8559 -

8978 -

8980 -

8982 -

8984 -

8986 -

8507 Positive PF, Phase C, Min Avg Dmd Timestamp TSTAMP 1Jan2000 - 31Dec2099 1 sec

8510 Negative PF, Phase A, Min Avg Dmd Timestamp TSTAMP 1Jan2000 - 31Dec2099 1 sec

8513 Negative PF, Phase B, Min Avg Dmd Timestamp TSTAMP 1Jan2000 - 31Dec2099 1 sec

8516 Negative PF, Phase C, Min Avg Dmd Timestamp TSTAMP 1Jan2000 - 31Dec2099 1 sec

8519 Reserved

8522 Reserved

8525 Reserved

8528 Reserved

8531 Reserved

8534 Reserved

8537 Symmetrical Comp Magnitude, 0 Seq, Min

Timestamp

8540 Symmetrical Comp Magnitude, + Seq, Min

Timestamp

8543 Symmetrical Comp Magnitude, - Seq, Min

Timestamp

8546 Symmetrical Comp Phase, 0 Seq, Min

Timestamp

8549 Symmetrical Comp Phase, + Seq, Min

Timestamp

8552 Symmetrical Comp Phase, - Seq, Min

Timestamp

8555 Unbalance, 0 Seq, Min Timestamp

8558 Unbalance, - Seq, Min Timestamp

8561 Current Unbalance, Min Timestamp

TSTAMP

TSTAMP

TSTAMP

TSTAMP

TSTAMP

TSTAMP

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1 sec

1 sec

1 sec

1 sec

1 sec

1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

8977 Volts A-N, previous Demand interval Short Term

Maximum

8979 Volts B-N, previous Demand interval Short Term

Maximum

8981 Volts C-N, previous Demand interval Short Term

Maximum

FLOAT

FLOAT

FLOAT

FLOAT 8983 Volts A-B, previous Demand interval Short Term

Maximum

8985 Volts B-C, previous Demand interval Short Term

Maximum

8987 Volts C-A, previous Demand interval Short Term

Maximum

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

read-only

Comments

Maximum instantaneous value measured during the demand interval before the one most recently completed.

# Reg

3

3

3

3

3

3

3

3

162

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-10

B: Modbus Map and Retrieving Logs

2351

2353

2355

2357

2359

235B

235D

235F

2361

2363

-

-

-

-

-

-

-

-

-

-

231B

231D

232F

2321

2323

2325

Primary Maximum Block

2327

2329

-

-

2328

232A

232B

232D

232F

2331

2333

2335

2337

2339

233B

233D

233F

2341

2343

-

-

-

-

-

-

-

-

-

-

-

-

-

232C

232E

2330

2332

2334

2336

2338

233A

233C

233E

2340

2342

2344

2345

2347

2349

234B

-

-

-

-

-

-

-

-

Modbus Address

Hex Decimal

231C

231E

2320

2322

2324

8988 -

8990 -

8992 -

8994 -

8996 -

Description (Note 1)

8989 Volts A-N, Maximum

8991 Volts B-N, Maximum

8993 Volts C-N, Maximum

8995 Volts A-B, Maximum

8997 Volts B-C, Maximum

2326 8998 -

2346

2348

234A

234C

9000 -

9002 -

9004 -

9006 -

9008 -

9010 -

9012 -

9014 -

9016 -

9018 -

9020 -

9022 -

9024 -

9026 -

9028 -

9030 -

9032 -

9034 -

9036 -

Format

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

Range (Note 6)

0 to 9999 M

0 to 9999 M

0 to 9999 M

0 to 9999 M

0 to 9999 M

8999 Volts C-A, Maximum FLOAT 0 to 9999 M

FLOAT

FLOAT

0 to 9999 M

0 to 9999 M

9001 Volts A-N, Maximum

9003 Volts B-N, Maximum

9005 Volts C-N, Maximum

9007 Volts A-B, Maximum

9009 Volts B-C, Maximum

9011 Volts C-A, Maximum

9013 Amps A, Maximum Avg Demand

9015 Amps B, Maximum Avg Demand

9017 Amps C, Maximum Avg Demand

9019 Positive Watts, 3-Ph, Maximum Avg Demand

9021 Positive VARs, 3-Ph, Maximum Avg Demand

9023 Negative Watts, 3-Ph, Maximum Avg Demand

9025 Negative VARs, 3-Ph, Maximum Avg Demand

9027 VAs, 3-Ph, Maximum Avg Demand

9029 Positive Power Factor, 3-Ph, Maximum Avg

Demand

9031 Negative Power Factor, 3-Ph, Maximum Avg

Demand

9033 Frequency, Maximum

9035 Neutral Current, Maximum Avg Demand

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

9037 Positive Watts, Phase A, Maximum Avg Demand FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

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

0 to 9999 M

0 to +9999 M

0 to +9999 M

0 to +9999 M

0 to +9999 M

-9999 M to +9999 M

-1.00 to +1.00

-1.00 to +1.00

0 to 65.00

0 to 9999 M

-9999 M to +9999 M none

Hz amps watts

Units or Resolution

volts volts volts volts volts volts volts volts volts amps amps amps watts

VARs watts

VARs

VAs none volts volts volts

Comments

Maximum instantaneous value measured during the most recently completed demand interval.

# Reg

2

2

2

2

2

2

12

read-only

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

2

234D

234F

-

-

234E

2350

9038 -

9040 -

9039 Positive Watts, Phase B, Maximum Avg Demand FLOAT

9041 Positive Watts, Phase C, Maximum Avg Demand FLOAT

-9999 M to +9999 M

-9999 M to +9999 M watts watts

2

2

2352

2354

2356

2358

235A

235C

235E

2360

2362

2364

9042 -

9044 -

9046 -

9048 -

9050 -

9052 -

9054 -

9056 -

9058 -

9060 -

9043 Positive VARs, Phase A, Maximum Avg Demand FLOAT

9045 Positive VARs, Phase B, Maximum Avg Demand FLOAT

9047 Positive VARs, Phase C, Maximum Avg Demand FLOAT

9049 Negative Watts, Phase A, Maximum Avg

Demand

9051 Negative Watts, Phase B, Maximum Avg

Demand

9053 Negative Watts, Phase C, Maximum Avg

Demand

9055 Negative VARs, Phase A, Maximum Avg

Demand

9057 Negative VARs, Phase B, Maximum Avg

Demand

9059 Negative VARs, Phase C, Maximum Avg

Demand

9061 VAs, Phase A, Maximum Avg Demand

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

FLOAT

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

-9999 M to +9999 M

VARs

VARs

VARs watts watts watts

VARs

VARs

VARs

VAs

2

2

2

2

2

2

2

2

2

2

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-11

B: Modbus Map and Retrieving Logs

24B7

24BA

24BD

24C0

24C3

24C6

24C9

24CC

24CF

24D2

24D5

2365

2367

2369

236B

236D

236F

2371

2373

2375

2376

2377

2378

2379

237A

237B

237D

237F

2381

2382

2383

2384

2385

2386

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

Modbus Address

Hex Decimal

2366 9062 -

Description (Note 1)

9063 VAs, Phase B, Maximum Avg Demand

2368 9064 9065 VAs, Phase C, Maximum Avg Demand

-

-

-

-

-

236A

236C

236E

2370

2372

2374

2375

2376

2377

2378

2379

237A

237C

237E

2380

2381

2382

2383

2384

2385

2386

9066 -

9068 -

9070 -

9072 -

9074 -

9076 -

9078 -

9079 -

9080 -

9081 -

9082 -

9083 -

9084 -

9086 -

9088 -

9090 -

9091 -

9092 -

9093 -

9094 -

9095 -

Primary Maximum Timestamp Block

Format

FLOAT

FLOAT

Range (Note 6)

-9999 M to +9999 M

-9999 M to +9999 M

9067 Positive PF, Phase A, Maximum Avg Demand

9069 Positive PF, Phase B, Maximum Avg Demand

9071 Positive PF, Phase C, Maximum Avg Demand

9073 Negative PF, Phase A, Maximum Avg Demand

9075 Negative PF, Phase B, Maximum Avg Demand FLOAT

9077 Negative PF, Phase C, Maximum Avg Demand FLOAT

9078 Reserved

9079 Reserved

9080 Reserved

9081 Reserved

FLOAT

FLOAT

FLOAT

FLOAT

9082 Reserved

9083 Reserved

9085 Symmetrical Component Magnitude, 0 Seq,

Maximum

9087 Symmetrical Component Magnitude, + Seq,

Maximum

9089 Symmetrical Component Magnitude, - Seq,

Maximum

9090 Symmetrical Component Phase, 0 Seq,

Maximum

9091 Symmetrical Component Phase, + Seq,

Maximum

9092 Symmetrical Component Phase, - Seq,

Maximum

9093 Unbalance, 0 Seq, Maximum

9094 Unbalance, - Seq, Maximum

9095 Current Unbalance, Maximum

FLOAT

FLOAT

FLOAT

SINT16

SINT16

SINT16

UINT16

UINT16

UINT16

-1.00 to +1.00

-1.00 to +1.00

-1.00 to +1.00

-1.00 to +1.00

-1.00 to +1.00

-1.00 to +1.00

0 to 9999 M

0 to 9999 M

0 to 9999 M

-1800 to +1800

-1800 to +1800

-1800 to +1800

0 to 10000

0 to 10000

0 to 20000

-

-

-

-

-

-

-

-

-

-

-

24B9

24BC

24BF

24C2

24C5

24C8

24CB

24CE

24D1

24D4

24D7

9400 -

9403 -

9406 -

9409 -

9412 -

9415 -

9418 -

9421 -

9424 -

9427 -

9430 -

Units or Resolution

VAs

VAs none none none none none none volts volts volts

0.1 degree

0.1 degree

0.1 degree

9402 Volts A-N, Max Timestamp

9405 Volts B-N, Max Timestamp

9408 Volts C-N, Max Timestamp

9411 Volts A-B, Max Timestamp

9414 Volts B-C, Max Timestamp

9417 Volts C-A, Max Timestamp

9420 Amps A, Max Avg Dmd Timestamp

9423 Amps B, Max Avg Dmd Timestamp

9426 Amps C, Max Avg Dmd Timestamp

TSTAMP

TSTAMP

TSTAMP

TSTAMP

TSTAMP

TSTAMP

TSTAMP

TSTAMP

TSTAMP

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1 sec

1 sec

1 sec

1 sec

1 sec

1 sec

1 sec

1 sec

1 sec

9429 Positive Watts, 3-Ph, Max Avg Dmd Timestamp TSTAMP 1Jan2000 - 31Dec2099 1 sec

9432 Positive VARs, 3-Ph, Max Avg Dmd Timestamp TSTAMP 1Jan2000 - 31Dec2099 1 sec

0.01%

0.01%

0.01%

read-only

24D8

24DB

-

-

24DA

24DD

9433 -

9436 -

9435 Negative Watts, 3-Ph, Max Avg Dmd Timestamp TSTAMP 1Jan2000 - 31Dec2099 1 sec

9438 Negative VARs, 3-Ph, Max Avg Dmd Timestamp TSTAMP 1Jan2000 - 31Dec2099 1 sec

24DE

24E1

24E4

24E7

-

-

-

-

24E0

24E3

24E6

24E9

9439 -

9442 -

9445 -

9448 -

9441 VAs, 3-Ph, Max Avg Dmd Timestamp

9444 Positive Power Factor, 3-Ph, Max Avg Dmd

Timestamp

9447 Negative Power Factor, 3-Ph, Max Avg Dmd

Timestamp

9450 Frequency, Max Timestamp

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

Comments

1

1

1

1

96

1

1

# Reg

2

2

1

1

2

2

1

1

2

2

2

2

1

1

2

2

2

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-12

B: Modbus Map and Retrieving Logs

24FF

2502

2505

2508

250B

250E

24EA

24ED

24F0

24F3

24F6

24F9

24FC

2511

2514

2517

251A

251D

2520

2523

2526

2529

252C

252F

2532

2535

2538

253B

253E

2541

2544

2547

254A

254D

2550

-

-

-

-

-

-

-

-

-

-

-

-

-

-

Modbus Address

Hex Decimal

24EC

24EF

9451 -

9454 -

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

24F2

24F5

24F8

24FB

24FE

2501

2504

2507

250A

250D

2510

2513

2516

2519

251C

9457 -

9460 -

9463 -

9466 -

9469 -

9472 -

9475 -

9478 -

9481 -

9484 -

9487 -

9490 -

9493 -

9496 -

9499 -

Description (Note 1) Format Range (Note 6) Units or Resolution

9453 Neutral Current, Max Avg Dmd Timestamp TSTAMP 1Jan2000 - 31Dec2100 1 sec

9456 Positive Watts, Phase A, Max Avg Dmd

Timestamp

9459 Positive Watts, Phase B, Max Avg Dmd

Timestamp

9462 Positive Watts, Phase C, Max Avg Dmd

Timestamp

9465 Positive VARs, Phase A, Max Avg Dmd

Timestamp

9468 Positive VARs, Phase B, Max Avg Dmd

Timestamp

9471 Positive VARs, Phase C, Max Avg Dmd

Timestamp

9474 Negative Watts, Phase A, Max Avg Dmd

Timestamp

9477 Negative Watts, Phase B, Max Avg Dmd

Timestamp

9480 Negative Watts, Phase C, Max Avg Dmd

Timestamp

9483 Negative VARs, Phase A, Max Avg Dmd

Timestamp

9486 Negative VARs, Phase B, Max Avg Dmd

Timestamp

9489 Negative VARs, Phase C, Max Avg Dmd

Timestamp

9492 VAs, Phase A, Max Avg Dmd Timestamp

TSTAMP

TSTAMP

TSTAMP

TSTAMP

TSTAMP

TSTAMP

TSTAMP

TSTAMP

TSTAMP

TSTAMP

TSTAMP

TSTAMP

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1 sec

1 sec

1 sec

1 sec

1 sec

1 sec

1 sec

1 sec

1 sec

1 sec

1 sec

1 sec

9495 VAs, Phase B, Max Avg Dmd Timestamp

9498 VAs, Phase C, Max Avg Dmd Timestamp

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

9501 Positive PF, Phase A, Max Avg Dmd Timestamp TSTAMP 1Jan2000 - 31Dec2099 1 sec

-

-

-

-

-

-

251F

2522

2525

2528

252B

252E

2531

2534

2537

253A

253D

2540

2543

2546

2549

254C

254F

2552

9502 -

9505 -

9508 -

9511 -

9514 -

9517 -

9520 -

9523 -

9526 -

9529 -

9532 -

9535 -

9538 -

9541 -

9544 -

9547 -

9550 -

9553 -

9504 Positive PF, Phase B, Max Avg Dmd Timestamp TSTAMP 1Jan2000 - 31Dec2099 1 sec

9507 Positive PF, Phase C, Max Avg Dmd Timestamp TSTAMP 1Jan2000 - 31Dec2099 1 sec

9510 Negative PF, Phase A, Max Avg Dmd

9513 Negative PF, Phase B, Max Avg Dmd

9516 Negative PF, Phase C, Max Avg Dmd

TSTAMP

TSTAMP

TSTAMP

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1 sec

1 sec

1 sec

9519 Reserved

9522 Reserved

9525 Reserved

9528 Reserved

9531 Reserved

9534 Reserved

9537 Symmetrical Comp Magnitude, 0 Seq, Max

Timestamp

9540 Symmetrical Comp Magnitude, + Seq, Max

Timestamp

9543 Symmetrical Comp Magnitude, - Seq, Max

Timestamp

9546 Symmetrical Comp Phase, 0 Seq, Max

Timestamp

9549 Symmetrical Comp Phase, + Seq, Max

Timestamp

9552 Symmetrical Comp Phase, - Seq, Max

Timestamp

9555 Unbalance, 0 Seq, Max Timestamp

TSTAMP

TSTAMP

TSTAMP

TSTAMP

TSTAMP

TSTAMP

TSTAMP

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1Jan2000 - 31Dec2099

1 sec

1 sec

1 sec

1 sec

1 sec

1 sec

1 sec

Comments # Reg

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

3

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-13

B: Modbus Map and Retrieving Logs

2553

2556

Modbus Address

Hex Decimal

2555 9556 -

Description (Note 1)

9558 Unbalance, - Seq, Max Timestamp

2558 9559 9561 Current Unbalance, Max Timestamp

Format Range (Note 6) Units or Resolution

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec

Resets Block (Note 9)

4E26

4E27

4E29

4E2B

4E2C

4E2D

4E2E

4E1F

4E20

4E21

4E22

4E23

4E24

4E25

-

-

-

-

-

-

-

-

-

-

-

-

-

-

4E1F

4E20

4E21

4E22

4E23

4E24

4E25

4E26

4E2E

4E2A

4E2B

4E2C

4E2D

4E2E

20000 -

20001 -

20002 -

20003 -

20004 -

20005 -

20006 -

20007 -

20008 -

20010 -

20012 -

20013 -

20014 -

20015 -

20000 Reset Max/Min Blocks

20001 Reset Energy Accumulators

20002 Reset Alarm Log (Note 21)

20003 Reset System Log (Note 21)

20004 Reset Historical Log 1 (Note 21)

20005 Reset Historical Log 2 (Note 21)

20006 Reset Historical Log 3 (Note 21)

20007 Reserved

20015 Reserved

20011 Reserved

20012 Reserved

20013 Reserved

20014 Reserved

20015 Reserved

Privileged Commands Block

5207

5208

5209

-

-

-

5207

5208

5209

21000 -

21001 -

21002 -

21000 Initiate Meter Firmware Reprogramming

21001 Force Meter Restart

21002 Open Privileged Command Session

Commands Section (Note 4)

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16 password (Note 5) password (Note 5) password (Note 5) password (Note 5) password (Note 5) password (Note 5) password (Note 5)

UINT16

UINT16

UINT16 password (Note 5) password (Note 5) password (Note 5)

520A

520B

520C

520D

520E

520F

5212

5213

521A

-

-

-

-

-

-

-

-

-

520A

520B

520C

520D

520E

5211

5212

5219

521A

Encryption Block

658F 659A

21003 -

21004 -

21005 -

21003 Initiate Programmable Settings Update

21004 Calculate Programmable Settings Checksum

(Note 3)

21005 Programmable Settings Checksum (Note 3)

UINT16

UINT16 password (Note 5)

0000 to 9999

UINT16 0000 to 9999

21006 -

21007 -

21008 -

21011 -

21012 -

21019 -

26000 -

21006 Write New Password (Note 3) UINT16 0000 to 9999

21007 Terminate Programmable Settings Update (Note

3)

21010 Set Meter Clock

UINT16

TSTAMP any value

1Jan2000 - 31Dec2099 1 sec

21011 Reserved

21018 Reserved

21019 Close Privileged Command Session UINT16 any value

26011 Perform a Secure Operation UINT16

Comments write-only

Reply to a reset log command indicates that the command was accepted but not necessarily that the reset is finished. Poll log status block to determine this.

Set to 0.

Reserved causes a watchdog reset, always reads 0 meter will process command registers (this register through 'Close Privileged Command Session' register below) for 5 minutes or until the session is closed, whichever comes first.

meter enters PS update mode meter calculates checksum on RAM copy of PS block read/write checksum register; PS block saved in nonvolatile memory on write (Note 8) write-only register; always reads zero meter leaves PS update mode via reset saved only when 3rd register is written

Reserved

Reserved ends an open command session

read/write

encrypted command to read password or change meter type

# Reg

3

3

159

1

1

1

1

1

1

1

1

7

1

3

1

20

1

16

1

1

2

1

1

2

1

1

1

1

1

1

1

12

12

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-14

B: Modbus Map and Retrieving Logs

Modbus Address

Hex Decimal

Basic Setups Block

752F 752F

7530

7531

7532

7533

7534

7535

-

-

-

-

-

-

7530

7531

7532

7533

7534

7535

30000 -

30001 -

30002 -

30003 -

30004 -

30005 -

30006 -

Description (Note 1)

30000 CT multiplier & denominator

30001 CT numerator

30002 PT numerator

30003 PT denominator

30004 PT multiplier & hookup

30005 Averaging Method

30006 Power & Energy Format

Format Range (Note 6)

Programmable Settings Section

Units or Resolution

UINT16

UINT16

UINT16

UINT16

UINT16 bit-mapped

1 to 9999

1 to 9999

1 to 9999 bit-mapped

Comments

dddddddd mmmmmmmm

write only in PS update mode

high byte is denominator (1 or 5, read-only), low byte is multiplier (1, 10, or 100) none none none mmmmmmmm mmmmhhhh mm…mm = PT multiplier (1, 10, 100, or 1000) hhhh = hookup enumeration (0 = 3 element wye[9S], 1 = delta 2 CTs[5S], 3 = 2.5 element wye[6S])

# Reg

1

1

1

1

1

UINT16 bit-mapped --iiiiii b----sss 1

UINT16 bit-mapped ppppiinn feee-ddd iiiiii = interval (5,15,30,60) b = 0-block or 1-rolling sss = # subintervals (1,2,3,4) pppp = power scale (0-unit, 3-kilo, 6-mega, 8-auto) ii = power digits after decimal point (0-3),

applies only if f=1 and pppp is not auto nn = number of energy digits (5-8 --> 0-3) eee = energy scale (0-unit, 3-kilo, 6-mega) f = decimal point for power

(0=data-dependant placement,

1=fixed placement per ii value) ddd = energy digits after decimal point (0-6)

See note 10.

1

7536 7536 30007 30007 Operating Mode Screen Enables UINT16 bit-mapped -------x eeeeeeee 1

7537 7537 30008 30008 Daylight Saving On Rule UINT16 bit-mapped hhhhhwww -dddmmmm eeeeeeee = op mode screen rows on/off, rows top to bottom are bits low order to high order x = set to suppress PF on W/VAR/PF screens applies only if daylight savings in User Settings Flags = on; specifies when to make changeover hhhhh = hour, 0-23 www = week, 1-4 for 1st - 4th, 5 for last ddd = day of week, 1-7 for Sun - Sat mmmm = month, 1-12

Example: 2AM on the 4th Sunday of March hhhhh=2, www=4, ddd=1, mmmm=3

1

7538

7539

-

-

7538

7539

30009 -

30010 -

30009 Daylight Saving Off Rule

30010 Time Zone UTC offset

UINT16

UINT16 bit-mapped bit-mapped hhhhhwww -dddmmmm z000 0000 hhhh hhmm

1

1

753A

753B

753C

-

-

-

753A

753B

753C

30011 -

30012 -

30013 -

30011 Clock Sync Configuration

30012 Reserved

30013 User Settings 2

UINT16 bit-mapped

UINT16 bit-mapped

0000 0000 mmm0 0ppe

-------- -------s mm = minutes/15; 00=00, 01=15, 10=30, 11=45 hhhh = hours; -23 to +23 z = Time Zone valid (0=no, 1=yes) i.e. register=0 indicates that time zone is not set while register=0x8000 indicates UTC offset = 0 e=enable automatic clock sync (0=no, 1=yes

Line pppp = expected frequency (0=60 Hz, 1=50 Hz)

Reserved s = display secondary volts (1=yes, 0=no)

1

1

1

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-15

B: Modbus Map and Retrieving Logs

753D

Modbus Address

Hex Decimal

753D 30014 -

Description (Note 1)

30014 DNP Options

753E 753E 30015 30015 User Settings Flags

Format

UINT16

Range (Note 6)

bit-mapped

Units or Resolution

-------- ww-i-vvp

Comments

p selects primary or secondary values for DNP voltage, current and power registers

(0=secondary, 1=primary) vv sets divisor for voltage scaling

(0=1, 1=10, 2=100) i sets divisor for current scaling

(0=1, 1=10) ww sets divisor for power scaling in addition to scaling for

Kilo

(0=1, 1=10, 2=100, 3=1000)

Example:

120KV, 500A, 180MW p=1, vv=2, i=0, and ww=3 voltage reads 1200, current reads 500, watts reads 180

# Reg

1

UINT16 bit-mapped vvkgeinn srpdywfa vv = number of digits after decimal point for voltage display.

0 - For voltage range (0 - 9999V)

1 - For voltage range (100.0kV - 999.9 kV)

2 - For voltage range (10.00kV - 99.99 kV)

3 - For voltage range ( 0kV - 9.999 kV)

This setting is used only when k=1.

k = enable fixed scale for voltage display.

(0=autoscale, 1=unit if vv=0 and kV if vv=1,2,3 ) g = enable alternate full scale bar graph current

(1=on, 0=off) e = enable ct pt compensation

(0=Disabled, 1=Enabled).

i = fixed scale and format current display

0=normal autoscaled current display

1=always show amps with no decimal places nn = number of phases for voltage & current screen

(3=ABC, 2=AB, 1=A, 0=ABC) s = scroll (1=on, 0=off) r = password for reset in use (1=on, 0=off) p = password for configuration in use (1=on, 0=off) d = daylight saving time changes (0=off, 1=on) y = diagnostic events in system log (1=yes, 0=no) w = power direction

(0=view as load, 1=view as generator) f = flip power factor sign (1=yes, 0=no) a = apparent power computation method

(0=arithmetic sum, 1=vector sum)

1

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-16

B: Modbus Map and Retrieving Logs

7549

754A

754B

754C

754D

754E

754F

7550

7555

755A

755F

7564

7569

756E

7573

7583

75C3

75C4

75C5

75C6

75C7

75C8

75C9

75CA

75CB

753F

7540

7548

75CC

Modbus Address

Hex Decimal

753F 30016 -

-

-

7547

7548

7549 30026 30026 COM2 setup

-

-

-

-

754A

754B

754C

754D

-

-

754E

754F

7554

7559

755E

7563

7568

756D

7572

7582

75C2

75C3

75C4

75C5

75C6

75C3

75C48

75C9

75CA

75CB

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

30027 -

30028 -

30027 COM2 address

30028 Limit #1 Identifier

30029 -

30030 -

30029 Limit #1 Out High Setpoint

30030 Limit #1 In High Threshold

UINT16

UINT16

1 to 247

0 to 65535

SINT16

SINT16

-200.0 to +200.0

-200.0 to +200.0

30031 -

30032 -

30031 Limit #1 Out Low Setpoint

30032 Limit #1 In Low Threshold

SINT16

SINT16

-200.0 to +200.0

-200.0 to +200.0

30033 -

30038 -

30043 -

30048 -

30053 -

30058 -

30063 -

30068 -

30084 -

30148 -

30149 -

30150 -

30151 -

30152 -

30153 -

30154 -

30155 -

30156 -

30037 Limit #2

30042 Limit #3

30047 Limit #4

30052 Limit #5

30057 Limit #6

30062 Limit #7

30067 Limit #8

30083 Reserved

30147 Reserved

30148 watts loss due to iron when watts positive

30149 watts loss due to copper when watts positive

30150 var loss due to iron when watts positive

30151 var loss due to copper when watts positive

30152 watts loss due to iron when watts negative

30153 watts loss due to copper when watts negative

SINT16

SINT16

SINT16

SINT16 same as Limit #1

SINT16

SINT16

SINT16

UINT16 0 to 99.99

UINT16

UINT16

0 to 99.99

0 to 99.99

UINT16

UINT16

UINT16

0 to 99.99

0 to 99.99

0 to 99.99

30154 var loss due to iron when watts negative

30155 var loss due to copper when watts negative

UINT16

UINT16

30156 transformer loss compensation user settings flag UINT16

0 to 99.99

0 to 99.99

bit-mapped

75E5 30157 30182 Reserved

Description (Note 1)

30016 Full Scale Current (for load % bar graph)

30017 -

30025 -

30024 Meter Designation

30025 COM1 setup

Format

UINT16

Range (Note 6)

0 to 9999

ASCII

UINT16

16 char bit-mapped

Units or Resolution

none none

----dddd -0100110

Comments

If non-zero and user settings bit g is set, this value replaces CT numerator in the full scale current calculation. (See Note 12) yy = parity (0-none, 1-odd, 2-even) dddd = reply delay (* 50 msec) ppp = protocol (1-Modbus RTU, 2-Modbus ASCII, 3-

DNP) bbbb = baud rate (1-9600, 2-19200, 4-38400, 6-57600,

13=1200, 14=2400, 15=4800)

# Reg

1

8

1

UINT16 bit-mapped ----dddd -ppp-bbb 1 none

0.1% of full scale

0.1% of full scale

0.1% of full scale

0.1% of full scale use Modbus address as the identifier (see notes 7, 11,

12)

Setpoint for the "above" limit (LM1), see notes 11-12.

Threshold at which "above" limit clears; normally less than or equal to the "above" setpoint; see notes 11-12.

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.

same as Limit #1 same as Limit #1

-------- ----cfwv

0.01%

0.01%

0.01%

Reserved

Reserved

0.01%

0.01%

0.01%

0.01%

0.01% c - 0 disable compensation for losses due to copper,

1 enable compensaion for losses due to copper f - 0 disable compensation for losses due to iron,

1 enable compensaion for losses due to iron w - 0 add watt compensation,

1 subtract watt compensation v - 0 add var compensation,

1 subtract var compensation

Reserved

64

1

1

1

5

16

5

5

5

5

5

5

1

1

1

1

1

1

1

1

1

1

1

1

26

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-17

B: Modbus Map and Retrieving Logs

7634

7635

7636

7637

763B

763F

7643

7647

75E6

75E7

7627

7628

7629

762A

762B

762F

7633

-

-

-

-

-

-

-

-

-

-

-

-

-

-

Modbus Address

Hex Decimal

75E6 30183 -

-

-

7626

762A

762B

7627

7628

7629

30184 -

30248 -

30249 -

30250 -

30251 -

30252 -

762F 30256 -

7633 30260 -

Description (Note 1)

30183 Programmable Settings Update Counter

Format

UINT16

Range (Note 6)

0-65535

30247 Reserved for Software Use

30248 A phase PT compensation @ 69V (% error)

30249 A phase PT compensation @ 120V (% error)

30250 A phase PT compensation @ 230V (% error)

30251 A phase PT compensation @ 480V (% error)

30255 B phase PT compensation @ 69V, 120V, 230V,

480V (% error)

30259 C phase PT compensation @ 69V, 120V, 230V,

480V (% error)

30260 A phase CT compensation @ c1 (% error)

SINT16

SINT16

SINT16

SINT16

SINT16

SINT16

SINT16

-99.99 to 99.99

-99.99 to 99.99

-99.99 to 99.99

-99.99 to 99.99

-99.99 to 99.99

-99.99 to 99.99

-99.99 to 99.99

Units or Resolution Comments

Increments each time programmable settings are changed; occurs when new checksum is calculated.

0.01%

Reserved

0.01%

0.01%

0.01%

0.01%

0.01%

0.01% For Class 10 unit c1=0.25A

c2=0.5A

c3=1A c4=5A

763E

764A

7634

7635

7636

7637

7642

7646

30261 -

30262 -

30263 -

30264 -

30268 -

30272 -

30276 -

30280 -

30261 A phase CT compensation @ c2 (% error)

30262 A phase CT compensation @ c3 (% error)

30263 A phase CT compensation @ c4 (% error)

30267 B phase CT compensation @ c1, c2, c3, c4 (% error)

30271 C phase CT compensation @ c1, c2, c3, c4 (% error)

30275 A phase PF compensation @ c1, c2, c3, c4 (% error)

30279 B phase PF compensation @ c1, c2, c3, c4 (% error)

30283 C phase PF compensation @ c1, c2, c3, c4 (% error)

SINT16

SINT16

SINT16

SINT16

SINT16

SINT16

SINT16

SINT16

-99.99 to 99.99

-99.99 to 99.99

-99.99 to 99.99

-99.99 to 99.99

-99.99 to 99.99

-99.99 to 99.99

-99.99 to 99.99

-99.99 to 99.99

0.01%

0.01%

0.01%

0.01%

0.01%

For Class 2 unit c1=0.05A

c2=0.1A

c3=0.2A

c4=1A

0.01%

0.01%

0.01%

# Reg

1

4

1

1

1

4

64

1

1

4

4

4

1

4

1

1

4

284

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-18

B: Modbus Map and Retrieving Logs

9C4B

9C4C

9C4D

9C4E

9C4F

9C50

9C51

9C52

9C53

9C54

Modbus Address

Hex Decimal

Log Setups Block

7917

7918

7919

791A

798E

79D7

7A97

7B57

-

-

-

-

-

-

-

-

7917

7918

7919

798D

79D6

7A96

7B56

7B57

31000 -

31001 -

31002 -

31003 -

31119 -

31192 -

31384 -

31576 -

Description (Note 1)

31000 Historical Log #1 Sizes

31001 Historical Log #1 Interval

Format

UINT16

Range (Note 6)

bit-mapped

UINT16 bit-mapped

31002 Historical Log #1, Register #1 Identifier UINT16

31118 Historical Log #1, Register #2 - #117 Identifiers UINT16

31191 Historical Log #1 Software Buffer

31383 Historical Log #2 Sizes, Interval, Registers &

Software Buffer

31575 Historical Log #3 Sizes, Interval, Registers &

Software Buffer

31607 Waveform Log Sample Rate & Pretrigger same as Historical Log #1 same as Historical Log #1

UINT16

0 to 65535

0 to 65535 bit-mapped

Units or Resolution

eeeeeeee ssssssss

00000000 hgfedcba

Comments

write only in PS update mode high byte is number of registers to log in each record (0-

117), low byte is number of flash sectors for the log (see note

19)

0 in either byte disables the log only 1 bit set: a=1 min, b=3 min, c=5 min, d=10 min, e=15 min, f=30 min, g=60 min, h=EOI pulse use Modbus address as the identifier (see note 7) same as Register #1 Identifier

Reserved for software use.

# Reg

1

1

1

116

73

192 ssssssss pppppppp High byte is samples/60Hz cycle = 5(32), 6(64), 7(128),

8(256), or 9(512)

Low byte is number of pretrigger cycles.

192

1

608

Secondary Block

9C40 -

9C41

9C42

-

-

9C43

9C44

9C45

9C46

-

-

-

-

9C47

9C48

9C49

-

-

-

9C4A -

9C40

9C41

9C42

9C43

9C44

9C45

9C46

9C47

9C48

9C49

9C4A

-

-

-

-

-

-

-

-

-

-

9C4B

9C4C

9C4D

9C4E

9C4F

9C50

9C51

9C52

9C53

9C54

40001 -

40002 -

40003 -

40004 -

40005 -

40006 -

40007 -

40008 -

40009 -

40010 -

40011 -

40012 -

40013 -

40014 -

40015 -

40016 -

40017 -

40018 -

40019 -

40020 -

40021 -

40001 System Sanity Indicator

40002 Volts A-N

40003 Volts B-N

40004 Volts C-N

40005 Amps A

40006 Amps B

40007 Amps C

40008 Watts, 3-Ph total

40009 VARs, 3-Ph total

40010 VAs, 3-Ph total

40011 Power Factor, 3-Ph total

40012 Frequency

40013 Volts A-B

40014 Volts B-C

40015 Volts C-A

40016 CT numerator

40017 CT multiplier

40018 CT denominator

40019 PT numerator

40020 PT multiplier

40021 PT denominator

Secondary Readings Section

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16

0 or 1

2047 to 4095

2047 to 4095

2047 to 4095

0 to 4095

0 to 4095

0 to 4095

0 to 4095

0 to 4095

2047 to 4095 none volts volts volts amps amps amps watts

VARs

VAs

UINT16 1047 to 3047 none

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16

0 to 2730

2047 to 4095

2047 to 4095

2047 to 4095

1 to 9999

1, 10, 100

1 or 5

1 to 9999

1, 10, 100, 1000

1 to 9999

Hz volts volts volts none none none none none none

read-only except as noted

0 indicates proper meter operation

2047= 0, 4095= +150 volts = 150 * (register - 2047) / 2047

0= -10, 2047= 0, 4095= +10 amps = 10 * (register - 2047) / 2047

0= -3000, 2047= 0, 4095= +3000 watts, VARs, VAs =

3000 * (register - 2047) / 2047

1047= -1, 2047= 0, 3047= +1

pf = (register - 2047) / 1000

0= 45 or less, 2047= 60, 2730= 65 or more freq = 45 + ((register / 4095) * 30)

2047= 0, 4095= +300 volts = 300 * (register - 2047) / 2047

CT = numerator * multiplier / denominator

PT = numerator * multiplier / denominator

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

1

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-19

B: Modbus Map and Retrieving Logs

9C7D

9C7E

9C7F

9C80

9C81

9C82

9C83

9C84

9C85

9C86

9C69

9C6B

9C6D

9C6F

9C71

9C73

9C75

9C77

9C79

9C7B

9C55

9C57

9C59

9C5B

9C5D

9C5F

9C61

9C63

9C65

9C67

9C87

9C88

9C89

9CA3

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

-

Modbus Address

Hex Decimal

9C56 40022 -

Description (Note 1)

40023 W-hours, Positive

9C58

9C5A

9C5C

9C5E

9C60

9C62

9C64

9C66

9C68

40024 -

40026 -

40028 -

40030 -

40032 -

40034 -

40036 -

40038 -

40040 -

40025 W-hours, Negative

40027 VAR-hours, Positive

40029 VAR-hours, Negative

40031 VA-hours

40033 W-hours, Positive, Phase A

40035 W-hours, Positive, Phase B

40037 W-hours, Positive, Phase C

40039 W-hours, Negative, Phase A

40041 W-hours, Negative, Phase B

9C7D

9C7E

9C7F

9C80

9C81

9C82

9C83

9C84

9C85

9C86

9C6A

9C6C

9C6E

9C70

9C72

9C74

9C76

9C78

9C7A

9C7C

9C87

9C88

9CA2

9CA3

40062 -

40063 -

40064 -

40065 -

40066 -

40067 -

40068 -

40069 -

40070 -

40071 -

40042 -

40044 -

40046 -

40048 -

40050 -

40052 -

40054 -

40056 -

40058 -

40060 -

40072 -

40073 -

40074 -

40100 -

40043 W-hours, Negative, Phase C

40045 VAR-hours, Positive, Phase A

40047 VAR-hours, Positive, Phase B

40049 VAR-hours, Positive, Phase C

40051 VAR-hours, Negative, Phase A

40053 VAR-hours, Negative, Phase B

40055 VAR-hours, Negative, Phase C

40057 VA-hours, Phase A

40059 VA-hours, Phase B

40061 VA-hours, Phase C

40062 Watts, Phase A

40063 Watts, Phase B

40064 Watts, Phase C

40065 VARs, Phase A

40066 VARs, Phase B

40067 VARs, Phase C

40068 VAs, Phase A

40069 VAs, Phase B

40070 VAs, Phase C

40071 Power Factor, Phase A

40072 Power Factor, Phase B

40073 Power Factor, Phase C

40099 Reserved

40100 Reset Energy Accumulators

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16

UINT16

UINT32

UINT32

UINT32

UINT32

UINT32

UINT32

UINT32

UINT32

UINT32

UINT32

UINT16

UINT16

N/A

UINT16

Format

UINT32

UINT32

UINT32

UINT32

UINT32

UINT32

UINT32

UINT32

UINT32

UINT32

Range (Note 6)

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 99999999

0 to 4095

0 to 4095

0 to 4095

0 to 4095

0 to 4095

0 to 4095

2047 to 4095

2047 to 4095

2047 to 4095

1047 to 3047

1047 to 3047

1047 to 3047

N/A password (Note 5)

Units or Resolution

Wh per energy format

Wh per energy format

VARh per energy format

VARh per energy format

VAh per energy format

Wh per energy format

Wh per energy format

Wh per energy format

Wh per energy format

Wh per energy format watts watts watts

VARs

VARs

VARs

VAs

VAs

VAs none

Wh per energy format

VARh per energy format

VARh per energy format

VARh per energy format

VARh per energy format

VARh per energy format

VARh per energy format

VAh per energy format

VAh per energy format

VAh per energy format none none none

Comments

* 5 to 8 digits

* decimal point implied, per energy format

* resolution of digit before decimal point = units, kilo, or

* see note 10

0= -3000, 2047= 0, 4095= +3000 watts, VARs, VAs =

3000 * (register - 2047) / 2047

1047= -1, 2047= 0, 3047= +1

pf = (register - 2047) / 1000

Reserved write-only register; always reads as 0

1

1

1

1

1

1

1

1

1

1

2

2

2

2

2

2

2

2

2

2

1

1

26

1

100

# Reg

2

2

2

2

2

2

2

2

2

2

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-20

B: Modbus Map and Retrieving Logs

C73D

C740

C743

C747

C757

C767

C777

C787

C7A7

C34F

C350

C351

Modbus Address

Hex Decimal

Log Retrieval Block

C34C C34D

C34E C34E

-

-

-

C34F

C350

C352

49997 -

49999 -

50000 -

50001 -

50002 -

Description (Note 1)

49998 Log Retrieval Session Duration

49999 Log Retrieval Session Com Port

50000 Log Number, Enable, Scope

50001 Records per Window or Batch, Record Scope

Selector, Number of Repeats

50003 Offset of First Record in Window

Format Range (Note 6)

Log Retrieval Section

UINT32

UINT16

0 to 4294967294

0 to 4

Units or Resolution

4 msec

UINT16

UINT16

UINT32 bit-mapped bit-mapped bit-mapped nnnnnnnn esssssss wwwwwwww snnnnnnn ssssssss nnnnnnnn nnnnnnnn nnnnnnnn

Comments read/write except as noted

0 if no session active; wraps around after max count

0 if no session active, 1-4 for session active on COM1 -

COM4 high byte is the log number (0-system, 1-alarm, 2history1, 3-history2, 4-history3, 5-I/O changes, 11waveform, (11 reserved for future use) e is retrieval session enable(1) or disable(0) sssssss is what to retrieve (0-normal record, 1timestamps only, 2-complete memory image (no data validation if image) high byte is records per window if s=0 or records per batch if s=1, low byte is number of repeats for function 35 or 0 to suppress auto-incrementing; max number of repeats is 8 (RTU) or 4 (ASCII) total windows, a batch is all the windows ssssssss is window status (0 to 7-window number, 0xFFnot ready); this byte is read-only.

nn…nn is a 24-bit record number. The log's first record is latched as a reference point when the session is enabled.

This offset is a record index relative to that point. Value provided is the relative index of the whole or partial record that begins the window.

# Reg

2

1

1

1

2

C353 C3CD

Log Status Block

C737

C739

C73B

C73C

-

-

-

-

C738

C73A

C73B

C73C

50004 50126 Log Retrieve Window

51000 -

51002 -

51004 -

51005 -

Alarm Log Status Block

51001 Log Size in Records

51003 Number of Records Used

51004 Record Size in Bytes

51005 Log Availability

-

-

-

-

-

-

-

-

-

C73F

C742

C746

C756

C766

C776

C786

C796

C7B6

51006 -

51009 -

51012 -

51016 -

51032 -

51048 -

51064 -

51080 -

51112 -

51008 Timestamp, First Record

51011 Timestamp, Last Record

51015 Reserved

51031 System Log Status Block

51047 Historical Log 1 Status Block

51063 Historical Log 2 Status Block

51079 Historical Log 3 Status Block

51095 Reserved

51127 Waveform Capture Log Status Block

UINT16 see comments none mapped per record layout and retrieval scope, read-only

UINT32

UINT32

UINT16

UINT16

0 to 4,294,967,294

1 to 4,294,967,294

14 to 242 record record byte none

TSTAMP 1Jan2000 - 31Dec2099 1 sec

TSTAMP 1Jan2000 - 31Dec2099 1 sec same as alarm log status block same as alarm log status block

0=available,

1-4=in use by COM1-4,

0xFFFF=not available (log size=0)

Reserved

Individual Log Status Block Size: same as alarm log status block same as alarm log status block same as alarm log status block

End of Map

123

130

4

16

3

3

16

16

16

16

16

16

128

1

1

2

2

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-21

B: Modbus Map and Retrieving Logs

13

14

15

16

8

9

10

11

4

5

2

3

6

7

Notes

1

12

Data Formats

ASCII

SINT16 / UINT16

SINT32 / UINT32

FLOAT

TSTAMP

17

ASCII characters packed 2 per register in high, low order and without any termination characters. For example, "Shark200" would be 4 registers containing 0x5378, 0x6172, 0x6B32, 0x3030.

16-bit signed / unsigned integer.

32-bit signed / unsigned integer spanning 2 registers. The lower-addressed register is the high order half.

32-bit IEEE floating point number spanning 2 registers. The lower-addressed register is the high order half (i.e., contains the exponent).

3 adjacent registers, 2 bytes each. First (lowest-addressed) register high byte is year (0-99), low byte is month (1-12). Middle register high byte is day(1-31), low byte is hour (0-23 plus DST bit).

DST (daylight saving time) bit is bit 6 (0x40). Third register high byte is minutes (0-59), low byte is seconds (0-59). For example, 9:35:07AM on October 12, 2049 would be 0x310A, 0x0C49, 0x2307, assuming DST is in effect.

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).

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.

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.

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.

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.

M denotes a 1,000,000 multiplier.

Each identifier is a Modbus register. For entities that occupy multiple registers (FLOAT, SINT32, etc.) all registers making up the entity must be listed, in ascending order. For example, to log phase A volts, VAs, voltage THD, and VA hours, the register list would be 0x3E7, 0x3E8, 0x411, 0x412, 0x176F, 0x61D, 0x61E and the number of registers (0x7917 high byte) would be 7.

Writing this register causes data to be saved permanently in nonvolatile memory. Reply to the command indicates that it was accepted but not whether or not the save was successful. This can only be determined after the meter has restarted.

Reset commands make no sense if the meter state is LIMP. An illegal function exception will be returned.

Energy registers should be reset after a format change.

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 address. If any of the 8 limits is unused, set its identifier to zero. If the indicated Modbus register is not used or is a nonsensical entity for limits, it will behave as an unused limit.

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 voltage

3 phase power single phase power

FS = CT numerator * CT multiplier

FS = PT numerator * PT multiplier

FS = CT numerator * CT multiplier * PT numerator * PT multiplier * 3 [ * SQRT(3) for delta hookup]

FS = CT numerator * CT multiplier * PT numerator * PT multiplier [ * SQRT(3) for delta hookup] frequency power factor percentage angle

FS = 60 (or 50)

FS = 1.0

FS = 100.0

FS = 180.0

THD not available shows 10000 in all THD and harmonic magnitude and phase registers for the channel. THD may be unavailable due to low V or I amplitude, delta hookup (V only), or V-switch setting.

Option Card Identification and Configuration Block is an image of the EEPROM on the card

A block of data and control registers is allocated for each option slot. Interpretation of the register data depends on what card is in the slot.

Measurement states: Off occurs during programmable settings updates; Run is the normal measuring state; Limp indicates that an essentail non-volatile memory block is corrupted; and Warmup occurs briefly

(approximately 4 seconds) at startup while the readings stabilize. Run state is required for measurement, historical logging, demand interval processing, limit alarm evaluation, min/max comparisons, and THD calculations. Resetting min/max or energy is allowed only in run and off states; warmup will return a busy exception. In limp state, the meter reboots at 5 minute intervals in an effort to clear the problem.

Limits evaluation for all entites except demand averages commences immediately after the warmup period. Evaluation for demand averages, maximum demands, and minimum demands commences at the end of the first demand interval after startup.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-22

B: Modbus Map and Retrieving Logs

18

19

20

21

Autoincrementing and function 35 must be used when retrieving waveform logs.

Depending on the V-switch setting, there are 15, 29, or 45 flash sectors available in a common pool for distribution among the 3 historical and waveform logs. The pool size, number of sectors for each log, and the number of registers per record together determine the maximum number of records a log can hold.

S = number of sectors assigned to the log,

H = number of Modbus registers to be monitored in each historical record (up to 117),

R = number of bytes per record = (12 + 2H) for historical logs

N = number of records per sector = 65516 / R, rounded down to an integer value (no partial records in a sector)

T = total number of records the log can hold = S * N

T = S * 2 for the waveform log.

Only 1 input on all digital input cards may be specified as the end-of-interval pulse.

Logs cannot be reset during log retrieval. Waveform log cannot be reset while storing a capture. Busy exception will be returned.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-23

B: Modbus Map and Retrieving Logs

This page intentionally left blank.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc# E149721 MM-24

C: DNP Mapping

C: DNP Mapping

C.1: Overview

This Appendix describes the functionality of the Shark® 200S meter's version of the

DNP protocol. A DNP programmer needs this information to retrieve data from the

Shark® 200S meter. The DNP version used by the Shark 200S is a reduced set of the

Distributed Network Protocol Version 3.0 subset 2; it gives enough functionality to get critical measurements from the Shark® 200S meter.

The Shark® 200S meter's DNP version supports Class 0 object/qualifiers 0,1,2,6, only. No event generation is supported. The Shark® 200S meter always acts as a secondary device (slave) in DNP communication.

A new feature allows DNP readings in primary units with user-set scaling for current,

Voltage, and power (see Chapter 8 in the Communicator EXT

TM

4.0 and MeterManager

EXT Software User Manual for instructions).

C.2: Physical Layer

The Shark® 200S meter's DNP version uses serial communication. Port 2 (RS485 compliant port) or any communication capable option board can be used. Speed and data format is transparent for the Shark® 200S meter's DNP version: they can be set to any supported value. The IrDA port cannot use DNP.

C.3: Data Link Layer

The Shark® 200S meter can be assigned a value from 1 to 65534 as the target device address. The data link layer follows the standard frame FT3 used by DNP

Version 3.0 protocol, but only 4 functions are implemented: Reset Link, Reset User,

Unconfirmed User Data, and Link Status, as depicted in the following table.

Function

Reset Link

Reset User 1

Unconfirmed User Data 4

Link Status

Function Code

0

9

Table C.1: Supported Link Functions

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 C-1

C: DNP Mapping

[dst] and [src] are the device address of the Shark® 200S meter and Master device, respectively. Refer to Section C.7 for more detail on supported frames for the data link layer.

In order to establish optimal communication with the Shark® 200S meter, we recommend that you perform the Reset Link and Reset User functions. The Link

Status is not mandatory, but can be performed as well. The inter-character time-out for DNP is 1 second. If this amount of time, or more, elapses between two consecutive characters within a FT3 frame, the frame will be dropped.

C.4: Application Layer

The Shark® 200S meter’s DNP version supports the Read, Write, Direct Operate and

Direct Operate Unconfirmed functions.

• The Read function (code 01) provides a means for reading the critical measurement data from the meter. This function should be posted to read object 60 variation 1, which will read all the available Class 0 objects from the DNP register map. See the register map in Section C.6. In order to retrieve all objects with their respective variations, the qualifier must be set to ALL (0x06). See Section C.7 for an example showing a read Class 0 request data from the meter.

• The Write function (code 02) provides a means for clearing the Device restart bit in the Internal Indicator register only. This is mapped to Object 80, point 0 with variation 1. When clearing the restart device indicator use qualifier 0. Section C.7 shows the supported frames for this function.

• The Direct Operate function (code 05) is intended for resetting the energy counters and the Demand counters (minimum and maximum energy registers). These actions are mapped to Object 12, points 0 and 2, which act as control relays. The relays must be operated (On) in 0 msec and released (Off) in 1 msec only. Qualifiers 0x17 or x28 are supported for writing the energy reset. Sample frames are shown in Section C.7.

• The Direct Operate Unconfirmed (or Unacknowledged) function (code 06) is intended for asking the communication port to switch to Modbus RTU protocol from

DNP. This switching acts as a control relay mapped into Object 12, point 1 in the meter. The relay must be operated with qualifier 0x17, code 3 count 0, with 0 milliseconds on and 1 millisecond off, only. After sending this request the current

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 C-2

C: DNP Mapping communication port will accept Modbus RTU frames only. To make this port go back to DNP protocol, the unit must be powered down and up. Section C.7 shows the constructed frame to perform DNP to Modbus RTU protocol change.

C.5: Error Reply

In the case of an unsupported function, or any other recognizable error, an error reply is generated from the Shark® 200S meter to the Primary station (the requester). The

Internal Indicator field will report the type of error: unsupported function or bad parameter.

The broadcast acknowledge and restart bit are also signaled in the Internal Indicator field, but they do not indicate an error condition.

C.6: Shark

®

200S Meter’s DNP Register Map

Object 10 - Binary Output States

Object Point Var

10 0 2

10

10

1

2

2

2

Description

Reset Energy

Counters

Change to

Modbus RTU

Protocol

Reset Demand

Cntrs (Max /

Min )

Format

BYTE

BYTE

BYTE

Range Multiplier Units

Always 1 N/A

Always 1 N/A

Always 1 N/A

None

None

None

Comments

Read by Class 0 or with qualifier 0, 1, 2, or 6

Read by Class 0 or with qualifier 0, 1, 2, or 6

Read by Class 0 or with qualifier 0, 1, 2, or 6

Object 12 - Control Relay Outputs

Object Point Var

12 0 1

Description

Reset Energy

Counters

12 1 1 Change to

Modbus RTU

Protocol

Format Range Multiplier Units

N/A N/A N/A none

N/A N/A N/A none

Comments

Responds to Function 5

(Direct Operate), Qualifier Code 17x or 28x,

Control Code 3, Count 0,

On 0 msec, Off 1 msec

ONLY.

Responds to Function 6

(Direct Operate - No

Ack), Qualifier Code

17x, Control Code 3,

Count 0, On 0 msec, Off

1 msec ONLY.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 C-3

C: DNP Mapping

Object Point Var

12 2 1

Description

Reset Demand

Counters (Max

/ Min)

Format Range Multiplier Units

N/A N/A N/A none

Comments

Responds to Function 5

(Direct Operate), Qualifier Code 17x or 28x,

Control Code 3, Count 0,

On 0 msec, Off 1 msec

ONLY.

Object 20 - Binary Counters (Primary Readings) - Read via Class 0 or with qualifier 0, 1, 2, or 6

Object Point Var

20 0 5

Description

W-hours,

Positive

20

20

20

20

1

2

3

4

5

5

5

5

W-hours,

Negative

VAR-hours,

Positive

VAR-hours,

Negative

VA-hours,

Total

Format

UINT32

Range

0 to

99999999

UINT32

UINT32

UINT32

UINT32

0 to

99999999

0 to

99999999

0 to

99999999

0 to

99999999

Multiplier

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.

Units

Whr

Comments

example: energy format =

7.2K and Whours counter =

1234567 n=3 (K scale), d=2 ( 2 digits after decimal point), multiplier = 10(3-2)

= 101 = 10, so energy is

1234567 * 10

Whrs, or

12345.67 KWhrs

Whr

VARhr

VARhr

VAhr

30

30

Object 30 - Analog Inputs (Secondary Readings) - Read via Class 0 or with qualifier 0, 1, 2, or 6

Object Point Var

30

30

0

1

4

4

Description

Meter Health

Volts A-N

Format

sint16 sint16

Range

0 or 1

0 to 32767

2

3

4

4

Volts B-N

Volts C-N sint16 sint16

0 to 32767

0 to 32767

Multiplier

N/A

(150 / 32768)

(150 / 32768)

(150 / 32768)

V

V

Units

None

V

Comments

0 = OK

Values above

150V secondary read 32767.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 C-4

C: DNP Mapping

Object Point Var

30 4 4

30

30

30

30

30

30

30

30

30

30

30

30

30

30

30

30

30

30

5

6

7

8

9

10

11

12

13

14

15

16

17

18

19

20

21

22

4

4

4

4

4

4

4

4

4

4

4

4

4

4

4

4

4

4

Description

Volts A-B

Volts B-C

Volts C-A

Amps A

Amps B

Amps C sint16 sint16

Watts, 3-Ph total

VARs, 3-Ph total sint16 sint16

VAs, 3-Ph total sint16

Power Factor,

3-Ph total

Frequency

Positive Watts,

3-Ph,

Maximum Avg

Demand

Positive VARs,

3-Ph,

Maximum Avg

Demand

Negative

Watts, 3-Ph,

Maximum Avg

Demand

Negative

VARs, 3-Ph,

Maximum Avg

Demand

VAs, 3-Ph,

Maximum Avg

Demand

Angle, Phase A

Current

Angle, Phase B

Current

Angle, Phase C

Current sint16 sint16 sint16 sint16 sint16 sint16 sint16 sint16 sint16 sint16

Format

sint16 sint16 sint16 sint16

Range

0 to 32767

0 to 32767

0 to 32767

0 to 32767

0 to 32767

0 to 32767

-32768 to

+32767

-32768 to

+32767

0 to +32767

(10 / 32768)

(10 / 32768)

(4500 /

32768)

(4500 /

32768)

(4500 /

32768)

0.001

-1000 to

+1000

0 to 9999

-32768 to

+32767

0.01

(4500 /

32768)

Multiplier

(300 / 32768)

(300 / 32768)

(300 / 32768)

(10 / 32768)

A

A

W

V

V

A

V

Units Comments

Values above

300V secondary read 32767.

Values above

10A secondary read 32767.

VAR

VA

None

Hz

W

-32768 to

+32767

-32768 to

+32767

-32768 to

+32767

-32768 to

+32767

-1800 to

+1800

-1800 to

+1800

-1800 to

+1800

(4500 /

32768)

(4500 /

32768)

(4500 /

32768)

(4500 /

32768)

0.1

0.1

0.1

VAR

W

VAR

VA degree degree degree

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 C-5

C: DNP Mapping

Object Point Var

30 23 4

30

30

30

30

30

30

30

30

30

24

25

26

27

28

29

30

31

32

4

4

4

4

4

4

4

4

4

Description

Angle, Volts

A-B

Angle, Volts

B-C

Angle, Volts

C-A

CT numerator

CT multiplier

CT denominator

PT numerator

PT multiplier

PT denominator

Neutral

Current

Format

sint16 sint16 sint16 sint16 sint16 sint16

Range Multiplier

-1800 to

+1800

-1800 to

+1800

0.1

0.1

-1800 to

+1800

0.1

1 to 9999 N/A

1, 10, or 100 N/A

1 or 5 N/A

SINT16

SINT16

SINT16

SINT16

1 to 9999

0 to 32767

N/A

1, 10, or 100 N/A

1 to 9999 N/A

(10 / 32768) none none none none none none

A

Units

degree

Comments

degree degree

CT ratio =

(numerator

* multiplier)

/ denominator

PT ratio =

(numerator

* multiplier)

/ denominator

For 1A model, multiplier is (2 /

32768) and values above

2A secondary read 32767

Object 80 - Internal Indicator

Object Point Var

80 7 1

Description Format Range Multiplier Units

Device Restart Bit N/A N/A N/A none

Comments

Clear via

Function 2

(Write),

Qualifier

Code 0.

C.7: DNP Message Layouts

Legend

All numbers are in hexadecimal base. In addition the following symbols are used.

dst 16 bit frame destination address src 16 bit frame source address crc DNP Cyclic redundant checksum (polynomial x

16

+x

13

+x

12

+x

11

+x

10

+x

7

+x

6

+x

5

+x

2

+1) x transport layer data sequence number y application layer data sequence number

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 C-6

C: DNP Mapping

Link Layer related frames

Reset Link

Request 05 64 05 C0 dst src crc

Reply 05 64 05 00 src dst crc

Reset User

Request 05 64 05 C1 dst src crc

Reply 05 64 05 00 src dst crc

Link Status

Request 05 64 05 C9 dst src crc

Reply 05 64 05 0B src dst crc

Application Layer related frames

Clear Restart

Request 05 64 0E C4 dst src crc

Cx Cy 02 50 01 00 07 07 00 crc

Reply 05 64 0A 44 src

Cx Cy 81 int. ind. crc dst crc

Class 0 Data

Request 05 64 0B C4 dst src

Cx Cy 01 3C 01 06 crc crc

Request

(alternate)

05 64 14 C4 dst src crc

Cx Cy 01 3C 02 06 3C 03 06 3C 04 06 3C 01 06 crc

Reply

(same for either request)

05 64 72 44 src pt 1

00 00 20 pt 0 pt6 pt 7 pt 15 pt 23 pt 31 pt 2 pt 8 pt 16 pt 24 pt 32 dst crc

Cx Cy 81 int. ind. 14 05 00 00 04 pt 0 pt 1 pt 3 pt 2 pt 3 pt 4 pt 4 pt 5 pt 1 crc

1E 04 crc pt6 crc pt 9 pt 17 pt 10 pt 18 pt 11 pt 19 pt 12 pt 20 pt 13 pt 21 pt 25 pt 26 pt 27 pt 28 pt 29

0A 02 00 00 02 pt0 pt1 pt2 crc crc crc crc

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 C-7

C: DNP Mapping

Reset Energy

Request 05 64 18 C4 dst src crc

Cx Cy 05 0C 01 17 01 00 03 00 00 00 00 00 01 00 crc

00 00 00 crc

Reply 05 64 1A 44 src

01 00 00 00 00 crc dst crc

Cx Cy 81 int. ind. 0C 01 17 01 00 03 00 00 00 00 00 crc

Request

(alternate)

05 64 1A C4 dst src crc

Cx Cy 05 0C 01 28 01 00 00 00 03 00 00 00 00 00 crc

01 00 00 00 00 crc

Reply 05 64 1C 44 src dst crc

Cx Cy 81 int. ind. 0C 01 28 01 00 00 00 03 00 00 00 crc

00 00 01 00 00 00 00 crc

Switch to Modbus

Request 05 64 18 C4 dst src crc

Cx Cy 06 0C 01 17 01 01 03 00 00 00 00 00 01 00 crc

00 00 00 crc

No Reply

Reset Demand (Maximums & Minimums)

Request 05 64 18 C4 dst src crc

Cx Cy 05 0C 01 17 01 02 03 00 00 00 00 00 01 00 crc

00 00 00 crc

Reply 05 64 1A 44 src

01 00 00 00 00 crc dst crc

Cx Cy 81 int. ind. 0C 01 17 01 02 03 00 00 00 00 00 crc

Request

( alternate

)

05 64 1A C4 dst src crc

Cx Cy 05 0C 01 28 01 02 00 00 03 00 00 00 00 00 crc

01 00 00 00 00 crc

Reply 05 64 1C 44 src dst crc

Cx Cy 81 int. ind. 0C 01 28 01 02 00 00 03 00 00 00 crc

00 00 01 00 00 00 00 crc

Reply

Error Reply

05 64 0A 44 src

Cx Cy 81 int. ind. crc dst crc

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 C-8

C: DNP Mapping

C.8: Internal Indication Bits

Bits implemented in the Shark® 200S meter are listed below. All others are always reported as zeroes.

Bad Function

Occurs if the function code in a User Data request is not Read (0x01), Write (0x02),

Direct Operate (0x05), or Direct Operate, No Ack (0x06).

Object Unknown

Occurs if an unsupported object is specified for the Read function. Only objects 10,

20, 30, and 60 are supported.

Out of Range

Occurs for most other errors in a request, such as requesting points that don’t exist or direct operate requests in unsupported formats.

Buffer Overflow

Occurs if a read request or a read response is too large for its respective buffer. In general, if the request overflows, there will be no data in the response while if the response overflows at least the first object will be returned. The largest acceptable request has a length field of 26, i.e. link header plus 21 bytes more, not counting checksums. The largest possible response has 7 blocks plus the link header.

Restart

All Stations

These 2 bits are reported in accordance with standard practice.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 C-9

C: DNP Mapping

This page intentionally left blank.

Electro

Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 C-10

D: Using the USB to IrDA Adapter

D: Using the USB to IrDA Adapter (CAB6490)

D.1: Introduction

Com 1 of the Shark® 200S meter is the IrDA port, located on the face of the meter.

One way to communicate with the IrDA port is with EIG's USB to IrDA Adapter

(CAB6490), which allows you to access the Shark® 200S meter's data from a PC. This

Appendix contains instructions for installing the USB to IrDA Adapter.

D.2: Installation Procedures

You can order CAB6490 from EIG’s webstore: www.electroind.com/store. Select

Cables and Accessories from the list on the left side of the screen. The USB to IrDA

Adapter comes packaged with a USB cable and an Installation CD. Follow this procedure to install the Adapter on your PC.

1. Connect the USB cable to the USB to IrDA Adapter, and plug the USB into your PC's

USB port.

2. Insert the Installation CD into your PC's CD ROM drive.

3. You will see the screen shown below. The Found New Hardware Wizard allows you to install the software for the Adapter. Click the Radio Button next to Install from

a list or specific location.

4. Click Next. You will see the screen shown on the next page.

Electro Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 D-1

D: Using the USB to IrDA Adapter

Select these options

5. Make sure the first Radio Button and the first Checkbox are selected, as shown above. These selections allow the Adapter's driver to be copied from the

Installation disk to your PC.

6. Click Next. You will see the screen shown below.

7. When the driver for the Adapter is found, you will see the screen shown on the next page.

Electro Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 D-2

D: Using the USB to IrDA Adapter

8. You do not need to be concerned about the message on the bottom of the screen.

Click Next to continue with the installation.

9. You will see the two windows shown below. Click Continue Anyway.

Electro Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 D-3

D: Using the USB to IrDA Adapter

10.You will see the screen shown below while the Adapter's driver is being installed on your PC.

11.When driver installation is complete, you will see the screen shown below.

12.Click Finish to close the Found New Hardware Wizard.

IMPORTANT! Do NOT remove the Installation CD until the entire procedure has been completed.

Electro Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 D-4

D: Using the USB to IrDA Adapter

13.Position the USB to IrDA Adapter so that it points directly at the IrDA on the front of the Shark® 200S meter. It should be as close as possible to the meter, and not more than 15 inches/38 cm away from it.

14.The Found New Hardware Wizard screen opens again. This time, click the Radio

Button next to Install the software automatically.

15.Click Next. You will see the screen shown below.

16.Make sure the first Radio Button and the first Checkbox are selected, as shown above screen. Click Next. You will see the two screens shown on the next page.

Electro Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 D-5

D: Using the USB to IrDA Adapter

Electro Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 D-6

D: Using the USB to IrDA Adapter

17.When installation is complete, you will see the screen shown below.

18.Click Finish to close the Found New Hardware Wizard.

19.To verify that your Adapter has been installed properly, click Start>Set-

tings>Control Panel>System>Hardware>Device Manager. The USB to IrDA

Adapter should appear under both Infrared Devices and Modems (click on the + sign to display all configured modems). See the example screen on the next page.

Electro Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 D-7

D: Using the USB to IrDA Adapter

NOTE: If the Adapter doesn't show up under Modems, move it away from the meter for a minute and then position it pointing at the IrDA, again.

20.Double-click on the Standard Modem over IR link (this is the USB to IrDA

Adapter). You will see the Properties screen for the Adapter.

21.Click the Modem tab. The Com Port that the Adapter is using is displayed in the screen.

22.Use this Com Port to connect to the meter from your PC, using the Communicator

EXT

TM

software. Refer to Chapter 3 of the Communicator EXT

TM

4.0 and MeterMan-

ager EXT Software User Manual for detailed connection instructions.

Electro Industries/GaugeTech

The Leader In Power Monitoring and Smart Grid Solutions

Doc

#

E149721 D-8

Was this manual useful for you? yes no
Thank you for your participation!

* Your assessment is very important for improving the work of artificial intelligence, which forms the content of this project

Download PDF

advertisement

Table of contents