734_IM

20130118

SEL-734Advanced Metering System

Instruction Manual

*PM734-01-NB*

SEL-734 Meter Instruction Manual Date Code 20130118

Equipment components are sensitive to electrostatic discharge (ESD). Undetectable permanent damage can result if you do not use proper ESD procedures. Ground yourself, your work surface, and this equipment before removing any cover from this equipment. If your facility is not equipped to work with these components, contact SEL about returning this device and related SEL equipment for service.

! CAUTION

There is danger of explosion if the battery is incorrectly replaced. Replace only with Ray-O-Vac® no. BR2335 or equivalent recommended by manufacturer. Dispose of used batteries according to the manufacturer’s instructions.

! CAUTION

Use of controls or adjustments, or performance of procedures other than those specified herein, may result in hazardous radiation exposure.

! CAUTION

Changes or modifications not expressly approved by the party responsible for compliance could void the user's authority to operate the equipment.

! CAUTION

Disconnect or de-energize all external connections before opening this device. Contact with hazardous voltages and currents inside this device can cause electrical shock resulting in injury or death.

! DANGER

Contact with instrument terminals can cause electrical shock that can result in injury or death.

! DANGER

Have only qualified personnel service this equipment. If you are not qualified to service this equipment, you can injure yourself or others, or cause equipment damage.

! WARNING

Use of this equipment in a manner other than specified in this manual can impair operator safety safeguards provided by this equipment.

! WARNING

This device is shipped with default passwords. Default passwords should be changed to private passwords at installation. Failure to change each default password to a private password may allow unauthorized access. SEL shall not be responsible for any damage resulting from unauthorized access.

! WARNING

Les composants de cet équipement sont sensibles aux décharges électrostatiques (DES). Des dommages permanents non-décelables peuvent résulter de l’absence de précautions contre les DES. Raccordez-vous correctement à la terre, ainsi que la surface de travail et l’appareil avant d’en retirer un panneau. Si vous n’êtes pas équipés pour travailler avec ce type de composants, contacter SEL afin de retourner l’appareil pour un service en usine.

! ATTENTION

Il y a un danger d’explosion si la pile électrique n’est pas correctement remplacée. Utiliser exclusivement Ray-O-Vac® No. BR2335 ou un équivalent recommandé par le fabricant. Se débarrasser des piles usagées suivant les instructions du fabricant.

! ATTENTION

L’utilisation de commandes ou de réglages, ou l’application de tests de fonctionnement différents de ceux décrits ci-après peuvent entraîner l’exposition à des radiations dangereuses.

! ATTENTION

Les changements ou modifications qui ne sont pas expressément approuvés par l'autorité responsable de se prononcer sur la conformité pourraient annuler le pouvoir de l'usager à actionner l'équipement.

! ATTENTION

Débrancher tous les raccordements externes avant d’ouvrir cet appareil. Tout contact avec des tensions ou courants internes à l’appareil peut causer un choc électrique pouvant entraîner des blessures ou la mort.

! DANGER

Tout contact avec les bornes de l’appareil peut causer un choc électrique pouvant entraîner des blessuers ou la mort.

! DANGER

Seules des personnes qualifiées peuvent travailler sur cet appareil. Si vous n’êtes pas qualifiés pour ce travail, vous pourriez vous blesser avec d’autres personnes ou endommager l’équipement.

! AVERTISSEMENT

L'utilisation de cet appareil suivant des procédures différentes de celles indiquées dans ce manuel peut désarmer les dispositifs de protection d'opérateur normalement actifs sur cet équipement.

! AVERTISSEMENT

Cet appareil est expédié avec des mots de passe par défaut. A l’installation, les mots de passe par défaut devront être changés pour des mots de passe confidentiels. Dans le cas contraire, un accés non-autorisé á l’équipement peut être possible. SEL décline toute responsabilité pour tout dommage résultant de cet accés non-autorisé.

! AVERTISSEMENT

© 2003–2013 by Schweitzer Engineering Laboratories, Inc. All rights reserved.

All brand or product names appearing in this document are the trademark or registered trademark of their respective holders. No SEL trademarks may be used without written permission. SEL products appearing in this document may be covered by U.S. and Foreign patents.

Schweitzer Engineering Laboratories, Inc. reserves all rights and benefits afforded under federal and international copyright and patent laws in its products, including without limitation software, firmware, and documentation.

The information in this manual is provided for informational use only and is subject to change without notice. Schweitzer Engineering Laboratories, Inc. has approved only the English language manual.

This product is covered by the standard SEL 10-year warranty. For warranty details, visit www.selinc.com or contact your customer service representative. PM734-01

Date Code 20130118 Instruction Manual SEL-734 Meter

Table of ContentsList of Tables ........................................................................................................................................................ v

List of Figures ................................................................................................................................................... xxi

Preface.............................................................................................................................................................xxxiii

Section 1: Introduction and SpecificationsOverview ......................................................................................................................................................... 1.1SEL-734 Meter Forms and Models ................................................................................................................. 1.1Applications..................................................................................................................................................... 1.3Hardware Connection Features ....................................................................................................................... 1.4Communications Connections......................................................................................................................... 1.6Specifications .................................................................................................................................................. 1.7

Section 2: InstallationOverview ......................................................................................................................................................... 2.1Meter Mounting............................................................................................................................................... 2.1Connection Diagrams ...................................................................................................................................... 2.3Making Rear-Panel Connections ..................................................................................................................... 2.9Circuit Board Connections ............................................................................................................................ 2.16

Section 3: PC SoftwareOverview ......................................................................................................................................................... 3.1Installation ....................................................................................................................................................... 3.1Starting ACSELERATOR QuickSet ................................................................................................................... 3.2ACSELERATOR QuickSet Design Templates ................................................................................................... 3.2

Section 4: MeteringOverview ......................................................................................................................................................... 4.1Four-Quadrant VAR Metering......................................................................................................................... 4.2Instrument Transformer Compensation........................................................................................................... 4.3Instantaneous Metering ................................................................................................................................... 4.6Demand Metering............................................................................................................................................ 4.7Energy Metering ............................................................................................................................................ 4.15Energy Interface ............................................................................................................................................ 4.16Maximum/Minimum Metering...................................................................................................................... 4.19Crest Factor Metering.................................................................................................................................... 4.21Harmonic Metering ....................................................................................................................................... 4.22Transformer/Line Loss Compensation .......................................................................................................... 4.25Load Profile Report ....................................................................................................................................... 4.32Metering Calculations ................................................................................................................................... 4.40

Section 5: Time-of-UseIntroduction ..................................................................................................................................................... 5.1Settings ............................................................................................................................................................ 5.1TOU Setup....................................................................................................................................................... 5.2TOU Glossary................................................................................................................................................ 5.11

Section 6: Power Quality and Event AnalysisOverview ......................................................................................................................................................... 6.1Event Reports .................................................................................................................................................. 6.2Example Standard 15-Cycle Event Report...................................................................................................... 6.6Sequential Events Recorder (SER) Report...................................................................................................... 6.8Example Sequential Events Recorder (SER) Report....................................................................................... 6.9

ii


Table of Contents

Voltage Sag/Swell/Interruption (VSSI) Report..............................................................................................6.10Flicker Meter..................................................................................................................................................6.14Harmonic Triggers and Logs .........................................................................................................................6.16

Section 7: Time-Synchronized MeasurementsOverview..........................................................................................................................................................7.1Meter Configuration for High-Accuracy Timekeeping ...................................................................................7.1Synchrophasor Measurements .........................................................................................................................7.3Power Flow Analysis .......................................................................................................................................7.8State Estimation Verification .........................................................................................................................7.11

Section 8: LogicOverview..........................................................................................................................................................8.1Optoisolated Inputs ..........................................................................................................................................8.2Remote Control Switches ................................................................................................................................8.4Latch Bits .........................................................................................................................................................8.5SELOGIC Control Equation Variables/Timers..................................................................................................8.9Math Variables ...............................................................................................................................................8.11Analog Control Values...................................................................................................................................8.11Counter Variables...........................................................................................................................................8.14KYZ Outputs..................................................................................................................................................8.16Output Contacts .............................................................................................................................................8.19Analog Output................................................................................................................................................8.20Rotating Display ............................................................................................................................................8.22

Section 9: SettingsOverview..........................................................................................................................................................9.1Settings Changes Via the Serial Port ...............................................................................................................9.1Meter Word Bits (Used in SELOGIC Control Equations).................................................................................9.2Meter Word Bits (Used in SELOGIC Control Equations).................................................................................9.5Settings Explanations.....................................................................................................................................9.14Settings Sheets ...............................................................................................................................................9.15

SEL-734 Settings Sheets

Section 10: CommunicationsOverview........................................................................................................................................................10.1Communications Options ..............................................................................................................................10.1Port Connector and Communications Cables ................................................................................................10.4Communications Protocols ............................................................................................................................10.8Command Summary ....................................................................................................................................10.13Command Explanations ...............................................................................................................................10.14SEL-734 Meter Command Summary ..........................................................................................................10.34

Section 11: Front-Panel OperationFront-Panel Layout ........................................................................................................................................11.1Normal Front-Panel Display ..........................................................................................................................11.2Front-Panel Automatic Messages ..................................................................................................................11.2Front-Panel Menus and Operations ...............................................................................................................11.2Front-Panel Main Menu.................................................................................................................................11.6

Section 12: Testing and TroubleshootingOverview........................................................................................................................................................12.1Testing Philosophy.........................................................................................................................................12.1Testing Methods and Tools ............................................................................................................................12.3Gain Adjustment ..........................................................................................................................................12.11Meter Self-Tests ...........................................................................................................................................12.12Meter Troubleshooting.................................................................................................................................12.13

iii


Table of Contents

Meter Calibration......................................................................................................................................... 12.15Factory Assistance....................................................................................................................................... 12.15

Appendix A: Firmware and Manual VersionsFirmware......................................................................................................................................................... A.1Instruction Manual........................................................................................................................................ A.10

Appendix B: SEL Distributed Port Switch Protocol (LMD)Overview .........................................................................................................................................................B.1Settings ............................................................................................................................................................B.1Operation .........................................................................................................................................................B.1

Appendix C: SEL Communications ProcessorsSEL Communications Protocols......................................................................................................................C.1SEL Communications Processor .....................................................................................................................C.3SEL Communications Processor and Meter Architecture...............................................................................C.5SEL Communications Processor Example......................................................................................................C.7

Appendix D: Setting SELOGIC Control EquationsOverview ........................................................................................................................................................ D.1Meter Word Bits ............................................................................................................................................. D.1SELOGIC Control Equations ........................................................................................................................... D.1Processing Order and Processing Interval ...................................................................................................... D.4

Appendix E: Distributed Network ProtocolOverview .........................................................................................................................................................E.1Configuration...................................................................................................................................................E.4EIA-232 Physical Layer Operation ...............................................................................................................E.17Ethernet Operation.........................................................................................................................................E.17Data-Link Operation......................................................................................................................................E.18Data Access Method......................................................................................................................................E.19Device Profile ................................................................................................................................................E.19Object Table...................................................................................................................................................E.20Data Map .......................................................................................................................................................E.22

Appendix F: Modbus RTU Communications ProtocolOverview ......................................................................................................................................................... F.1Modbus RTU Communications Protocol ........................................................................................................ F.1

Appendix G: MIRRORED BITS CommunicationsOverview ........................................................................................................................................................ G.1Operation ........................................................................................................................................................ G.1MIRRORED BITS Protocol for Pulsar 9600 Baud Modem............................................................................... G.4Settings ........................................................................................................................................................... G.4

Appendix H: Analog Quantities

Glossary

Index

SEL-734 Meter Command Summary

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List of TablesTable 1.1 SEL-734 Form Numbers ........................................................................................................ 1.1Table 1.2 SEL-734 Feature Availability................................................................................................. 1.2Table 2.1 SEL-734 Power Supply Fuse Requirements ........................................................................ 2.10Table 2.2 Communication Cables Used to Connect the SEL-734 to Other Devices ........................... 2.15Table 2.3 Optical Port Probes............................................................................................................... 2.15Table 4.1 Example Current Transformer Test Data ............................................................................... 4.4Table 4.2 Metering Quantity Definitions ............................................................................................... 4.6Table 4.3 Demand and Peak Demand Metering Values......................................................................... 4.7Table 4.4 Demand Meter Settings and Settings Ranges ...................................................................... 4.10Table 4.5 Time = 5 Minutes Intervals .................................................................................................. 4.10Table 4.6 Time = 10 Minutes Intervals ................................................................................................ 4.11Table 4.7 Time = 15 Minutes Intervals ................................................................................................ 4.11Table 4.8 Demand Meter Settings and Settings Range ........................................................................ 4.12Table 4.9 Present and Peak Demand Values ........................................................................................ 4.14Table 4.10 Example ANGCUT Setting.................................................................................................. 4.16Table 4.11 Energy Interface Table ......................................................................................................... 4.17Table 4.12 FAULT Thresholds ............................................................................................................... 4.20Table 4.13 Meter Power Calculation Corrections According to Meter Position ................................... 4.26Table 4.14 Analog Values Affected by Transformer/Line Loss Compensation..................................... 4.26Table 4.15 Required User Input ............................................................................................................. 4.27Table 4.16 Settings for Example Loss Calculations............................................................................... 4.30Table 4.17 Load Profile Recorder Settings and Commands .................................................................. 4.32Table 4.18 LDP Functions...................................................................................................................... 4.33Table 4.19 LDP Serial Port Commands ................................................................................................. 4.34Table 4.20 LDP File Transfer Commands ............................................................................................. 4.35Table 4.21 LDP Field Format................................................................................................................. 4.35Table 4.22 Meter Configuration Record ................................................................................................ 4.36Table 4.23 SEL-734 Load Profile Record Response.............................................................................. 4.38Table 4.24 Record Type 0065—Present Values ..................................................................................... 4.38Table 4.25 Record Type 0066—Meter Status ........................................................................................ 4.39Table 4.26 Record Type 0067—LDP Data ............................................................................................ 4.39Table 4.27 Status Nibble Definitions ..................................................................................................... 4.40Table 4.28 Record Type 0068—SER Data............................................................................................. 4.40Table 4.29 Record Type 0069—LDP Error ........................................................................................... 4.40Table 5.1 Available Time-of-Use Data................................................................................................... 5.9Table 6.1 Example EVE Commands...................................................................................................... 6.3Table 6.2 Standard Event Report Current, Voltage, and Frequency Columns ....................................... 6.5Table 6.3 Example SER Serial Port Commands .................................................................................... 6.8Table 6.4 Sequential Events Recorder Explanation ............................................................................... 6.9Table 6.5 Element Status Columns ...................................................................................................... 6.12Table 6.6 Status VSSI Column............................................................................................................. 6.12Table 6.7 Example SSI Commands...................................................................................................... 6.14Table 7.1 Required Synchrophasor Settings .......................................................................................... 7.4Table 7.2 PMDATA Setting for Synchrophasor Fast Message Data Selection (Form 9 Meter) ............ 7.5Table 7.3 SEL Fast Message Protocol Format ....................................................................................... 7.5Table 7.4 Unsolicited Write Message Transmission Rates .................................................................... 7.6Table 7.5 Minimum Bandwidth Requirements ...................................................................................... 7.7Table 7.6 Unsolicited Fast Message Enable Packet ............................................................................... 7.7Table 7.7 Unsolicited Fast Message Disable Packet .............................................................................. 7.8Table 7.8 Meter Voltage and Current Measurement .............................................................................. 7.9Table 8.1 SEL-734 Logic Inputs and Outputs........................................................................................ 8.1Table 8.2 Operator Precedence ............................................................................................................ 8.10Table 8.3 Error Codes of DNP3 Writes to ACV Registers .................................................................. 8.14Table 8.4 Counter Inputs and Outputs.................................................................................................. 8.14

vi List of Tables


Table 8.5 KYZ Energy Values..............................................................................................................8.16Table 8.6 KYZ Output Settings and Ranges ........................................................................................8.17Table 8.7 Analog Output Settings ........................................................................................................8.21Table 8.8 Example Connection Details ................................................................................................8.21Table 8.9 Display Point Test Definitions..............................................................................................8.23Table 8.10 Display Point Formatting......................................................................................................8.24Table 9.1 Serial Port SET Commands ....................................................................................................9.1Table 9.2 SET Command Editing Keystrokes ........................................................................................9.2Table 9.3 SEL-734 Meter Word Bits ......................................................................................................9.2Table 9.4 SEL-734 Meter Word Bit Definitions.....................................................................................9.5Table SET.1 Valid IP Addresses........................................................................................................... SET.13Table 10.1 Modem Settings ....................................................................................................................10.1Table 10.2 Useful AT Commands ..........................................................................................................10.2Table 10.3 Useful Dialing Modifiers ......................................................................................................10.3Table 10.4 Ethernet Port LED Description.............................................................................................10.5Table 10.5 Port Pinout Functions ...........................................................................................................10.5Table 10.6 Serial Communications Port Pin/Terminal Function Definitions .........................................10.8Table 10.7 Serial Port Automatic Messages.........................................................................................10.11Table 10.8 MET CF Command Displayed Quantities..........................................................................10.19Table 10.9 MET D Command Displayed Values .................................................................................10.19Table 10.10 MET E Command Displayed Quantities ............................................................................10.20Table 10.11 MET Command Displayed Magnitudes .............................................................................10.22Table 10.12 MET M Command Displayed Quantities ...........................................................................10.23Table 10.13 MET PM Displayed Quantities ..........................................................................................10.23Table 10.14 SHO Command Options .....................................................................................................10.24Table 10.15 STA Abbreviation Definitions ............................................................................................10.25Table 10.16 TAR Command Options .....................................................................................................10.26Table 10.17 SEL-734 Meter Word and Its Correspondence to TAR Command ....................................10.26Table 10.18 SEL-734 Meter Control Subcommands .............................................................................10.29Table 10.19 Factory Default Passwords .................................................................................................10.31Table 10.20 Main Board Jumpers...........................................................................................................10.32Table 10.21 STA S Command ................................................................................................................10.33Table 10.22 STA SC and STA SR Command.........................................................................................10.33Table 10.23 Command Summary ...........................................................................................................10.34Table 11.1 Front-Panel Automatic Messages .........................................................................................11.2Table 11.2 Front-Panel Pushbutton Functions........................................................................................11.3Table 12.1 Meter Testing Features .........................................................................................................12.3Table 12.2 Default Meter Test Pulse Weights ........................................................................................12.7Table 12.3 IEEE Recommended Test Pulses........................................................................................12.10Table 12.4 Values Affected by WGAIN and VARGAIN .....................................................................12.11Table 12.5 Meter Self-Tests..................................................................................................................12.13Table A.1 Firmware Revision History for R2xx/R6xx Series—S/N 2009315xxx and Later ................A.1Table A.2 Firmware Revision History for R1xx/R5xx Series—S/N 2009314xxx and Earlier..............A.3Table A.3 Instruction Manual Revision History...................................................................................A.10Table C.1 Supported Serial Command Sets ........................................................................................... C.1Table C.2 Compressed ASCII Commands............................................................................................. C.2Table C.3 SEL Communications Processors Protocol Interfaces .......................................................... C.5Table C.4 SEL Communications Processor Port 1 Settings................................................................... C.8Table C.5 SEL Communications Processor Data Collection Auto-messages........................................ C.8Table C.6 SEL Communications Processor Port 1 Automatic Messaging Settings .............................. C.8Table C.7 SEL Communications Processor Port 1 Region Map............................................................ C.9Table C.8 Communications Processor METER Region Map ................................................................ C.9Table D.1 SELOGIC Control Equation Operators (Listed in Processing Order) ....................................D.2Table D.2 SELOGIC Control Equation Settings Limitations for the SEL-734 Meter Model .................D.3Table D.3 Processing Order of Meter Elements and Logic (Top to Bottom).........................................D.4Table E.1 Power Factor Analog and Binary Points................................................................................ E.1Table E.2 VSSI Record Status Report Definitions ................................................................................ E.3Table E.3 Phase VSSI Column Definitions ........................................................................................... E.3

viiList of Tables


Table E.4 SEL-734 DNP3 Default Data Map.........................................................................................E.4Table E.5 SEL-734 DNP3 Default Variations ........................................................................................E.5Table E.6 DNP3 Device Profile..............................................................................................................E.6Table E.7 DNP-IP Specific Settings .....................................................................................................E.17Table E.8 Data Access Methods ...........................................................................................................E.19Table E.9 SEL-734 DNP3 Device Profile ............................................................................................E.19Table E.10 SEL-734 DNP Object List....................................................................................................E.20Table E.11 Event Causes ........................................................................................................................E.22Table E.12 Fault Type.............................................................................................................................E.22Table E.13 Control Field ........................................................................................................................E.23Table F.1 Modbus Query Fields ............................................................................................................. F.1Table F.2 SEL-734 Meter Modbus Function Codes............................................................................... F.2Table F.3 SEL-734 Meter Modbus Exception Codes............................................................................. F.2Table F.4 01h Read Coil Status Commands........................................................................................... F.3Table F.5 Meter Responses to 01h Read Coil Query Errors .................................................................. F.3Table F.6 02h Read Input Status Command........................................................................................... F.4Table F.7 SEL-734 Meter Inputs............................................................................................................ F.4Table F.8 Responses to 02h Read Input Query Errors ........................................................................... F.4Table F.9 03h Read Holding Register Command................................................................................... F.5Table F.10 Responses to 03h Read Holding Register Query Errors ........................................................ F.5Table F.11 04h Read Holding Register Command................................................................................... F.6Table F.12 Responses to 04h Read Holding Register Query Errors ........................................................ F.6Table F.13 05h Force Single Coil Command ........................................................................................... F.6Table F.14 SEL-734 Meter Output Coils (FC05h)................................................................................... F.7Table F.15 Responses to 05h Force Singe Coil Query Errors.................................................................. F.7Table F.16 06h Preset Single Register Command.................................................................................... F.7Table F.17 Responses to 06h Preset Single Register Query Errors.......................................................... F.7Table F.18 08h Loopback Diagnostic Command..................................................................................... F.8Table F.19 Responses to 08h Loopback Diagnostic Query Errors........................................................... F.8Table F.20 10h Preset Multiple Registers Command............................................................................... F.8Table F.21 Responses to 10h Preset Multiple Registers Query Errors .................................................... F.9Table F.22 Modbus Conversion.............................................................................................................. F.10Table F.23 Modbus Register Map .......................................................................................................... F.11Table F.24 Sequence of Event Enumerations......................................................................................... F.30Table F.25 Load Profile Status Enumeration ......................................................................................... F.30Table F.26 Load Profile Record Status Bits ........................................................................................... F.30Table F.27 Example Load Profile Status Enumeration .......................................................................... F.31Table G.1 Using the SPEED Setting to Control MIRRORED BIT Rates ................................................. G.4Table G.2 Matching RX_ID of Local Meter to TX_ID of Remote Meter............................................. G.5Table H.1 Instantaneous and RMS Quantities ....................................................................................... H.2Table H.2 Demand Metering.................................................................................................................. H.4Table H.3 Peak Demand Metering......................................................................................................... H.5Table H.4 Energy Metering.................................................................................................................... H.7Table H.5 Monthly Frozen/Consumed Energy Values........................................................................... H.8Table H.6 DST Change Frozen/Consumed Energy Values.................................................................... H.9Table H.7 TOU Season Change Frozen/Consumed Energy Values....................................................... H.9Table H.8 Maximum/Minimum Metering ........................................................................................... H.10Table H.9 Harmonics Metering............................................................................................................ H.10Table H.10 Flicker Metering .................................................................................................................. H.11Table H.11 Diagnostics .......................................................................................................................... H.12Table H.12 Date/Time............................................................................................................................ H.12Table H.13 SELOGIC Counters .............................................................................................................. H.12Table H.14 SELOGIC Math Variables..................................................................................................... H.12Table H.15 DNP Remote Analog Output Objects ................................................................................. H.12Table H.16 Analog Control Values ........................................................................................................ H.13Table H.17 Analog Inputs ...................................................................................................................... H.13

viii List of Tables


Table H.18 Transformer Ratio Settings..................................................................................................H.13Table H.19 Prefix and Qualifier Descriptions ........................................................................................H.13Table H.20 Time-of-Use.........................................................................................................................H.13


List of FiguresFigure 1.1 SEL-734 Applied at Billing Points Throughout the Power System....................................... 1.3Figure 1.2 SEL-734 Inputs, Outputs, and Communications Ports .......................................................... 1.4Figure 1.3 SEL-734 Extra I/O Board (Expansion Slot #2)...................................................................... 1.5Figure 1.4 SEL-734 Communications Connection Examples................................................................. 1.6Figure 2.1 SEL-734 Horizontal Panel-Mount Dimensions ..................................................................... 2.1Figure 2.2 SEL-734 Vertical Panel-Mount Dimensions .......................................................................... 2.2Figure 2.3 SEL-734 Easily Extractable Meter (EXM) Mounting Dimensions ....................................... 2.2Figure 2.4 SEL-734T Panel-Mount Dimensions ..................................................................................... 2.3Figure 2.5 SEL-734 Horizontal Front-Panel Drawing............................................................................. 2.4Figure 2.6 SEL-734 Vertical Front-Panel Drawing ................................................................................. 2.5Figure 2.7 SEL-734B Front Panel ........................................................................................................... 2.6Figure 2.8 SEL-734T Front Panel ........................................................................................................... 2.6Figure 2.9 Side- and Rear-Panel Drawings for Typical Meters With CT Inputs ..................................... 2.7Figure 2.10 Side- and Rear-Panel Drawings for Typical Meters With LEA Inputs .................................. 2.8Figure 2.11 Grounding Terminal Symbol.................................................................................................. 2.9Figure 2.12 Form 9, 3-Element, 4-Wire Wye .......................................................................................... 2.12Figure 2.13 Form 5, 2-Element, 3-Wire Delta......................................................................................... 2.13Figure 2.14 Connector and Major Component Locations on the

SEL-734 Main Board (Models 0734ES2-XX and 0734ES2-6X) .................................... 2.17Figure 4.1 IEEE VAR Sign Convention................................................................................................... 4.2Figure 4.2 SEL-734 Power Flow Notations............................................................................................. 4.2Figure 4.3 Ratio Correction Factor vs. Calibration Point ........................................................................ 4.5Figure 4.4 Phase Angle Minutes vs. Calibration Point............................................................................ 4.5Figure 4.5 Response of Thermal, Rolling, and Block Demand

Meters to a Step Input (Setting DMTC=15 Minutes)......................................................... 4.8Figure 4.6 Voltage VS Applied to Series RC Circuit .............................................................................. 4.9Figure 4.7 PREDAL Logic .................................................................................................................... 4.12Figure 4.8 Demand Current Logic Outputs ........................................................................................... 4.13Figure 4.9 Power Factor = 1 .................................................................................................................. 4.15Figure 4.10 Power Factor = 0 .................................................................................................................. 4.16Figure 4.11 Power Factor = ±0.02............................................................................................................ 4.16Figure 4.12 FAULT and DFAULT Meter Word Bit Logic....................................................................... 4.20Figure 4.13 Interharmonics vs. Integer-Harmonics Example at the Third Harmonic ............................. 4.23Figure 4.14 Meter and Billing Positions.................................................................................................. 4.25Figure 4.15 Example System Values ....................................................................................................... 4.29Figure 5.1 Setup Page .............................................................................................................................. 5.2Figure 5.2 Rate Schedules Page............................................................................................................... 5.3Figure 5.3 Schedule Drop-Down Menu................................................................................................... 5.3Figure 5.4 Deleting a Rate Schedule ....................................................................................................... 5.4Figure 5.5 Renaming a Rate Schedule..................................................................................................... 5.4Figure 5.6 Modifying a Rate Schedule .................................................................................................... 5.5Figure 5.7 Calendar Page......................................................................................................................... 5.6Figure 5.8 Calendar Entry Drop-Down Menu ......................................................................................... 5.7Figure 5.9 Calendar Entry Editor............................................................................................................. 5.7Figure 5.10 Calendar Entry Editor............................................................................................................. 5.7Figure 5.11 Quick Set Menu...................................................................................................................... 5.8Figure 5.12 TOU Data Page ...................................................................................................................... 5.8Figure 5.13 Total At/Since Demand Reset .............................................................................................. 5.11Figure 5.14 Peak Cumulative Demand .................................................................................................... 5.12Figure 6.1 Standard Event Report Summary........................................................................................... 6.3Figure 6.2 Typical Auto Message Response............................................................................................ 6.5Figure 6.3 Example Standard 15-Cycle Event Report

1/16-Cycle Resolution (Wye-Connected PTs).................................................................... 6.7Figure 6.4 Example Sequential Events Recorder (SER) Report ............................................................. 6.9

x List of Figures


Figure 6.5 ACSELERATOR QuickSet VSSI Report With CBEMA/ITIC and Disturbance Analysis .....6.10Figure 6.6 Example VSSI Response in ACSELERATOR QuickSet.........................................................6.11Figure 6.7 Example Voltage Sag/Swell/Interruption (VSSI) Report (Meter Form 9) ...........................6.13Figure 6.8 Example Voltage Sag/Swell/Interruption (VSSI) Report (Meter Form 5) ...........................6.13Figure 6.9 LDP Flicker Settings.............................................................................................................6.15Figure 6.10 Flicker Trend From LDP ......................................................................................................6.16Figure 7.1 High-Accuracy Timekeeping Connections.............................................................................7.2Figure 7.2 500 kV Three Bus Power System...........................................................................................7.9Figure 7.3 Power Flow Solution ............................................................................................................7.10Figure 8.1 Example Operation of Optoisolated Inputs

IN101 Through IN102 (Models 0734ES2-XX and 0734ES2-6X) .....................................8.2Figure 8.2 Example Operation of Optoisolated Inputs

IN401 Through IN404, Extra I/O Board (Model 0734ES2-6X).........................................8.3Figure 8.3 Remote Control Switches Drive Remote Bits RB01 Through RB16.....................................8.4Figure 8.4 Traditional Latching Relay .....................................................................................................8.5Figure 8.5 Latch Control Switches Drive Latch Bits LT01 Through LT32 .............................................8.6Figure 8.6 Battery Charger Health Status Contact Pulses

Input IN102 to Enable/Disable ALARM Output Contact ..................................................8.7Figure 8.7 Single Input to Control ALARM............................................................................................8.7Figure 8.8 Latch Control Switch Operation Time Line ...........................................................................8.7Figure 8.9 Latch Control Switch (With Time-Delay Feedback) Operation Time Line ...........................8.8Figure 8.10 SELOGIC Control Equation Variables/Timers SV01/SV01T Through SV32/SV32T ..........8.10Figure 8.11 Example Use of SELOGIC Variables/Timers ........................................................................8.11Figure 8.12 ACV Register Alias Example ...............................................................................................8.12Figure 8.13 Change ACV Register Value From the Front Panel .............................................................8.13Figure 8.14 SELOGIC Variable SV10 Timing Logic ................................................................................8.15Figure 8.15 SELOGIC Control Equation Counter Example......................................................................8.16Figure 8.16 KYZ Pulse Pickup ................................................................................................................8.18Figure 8.17 Logic Flow for Example Output Contact Operation ............................................................8.20Figure 8.18 Example SEL-734 Connected to an RTU.............................................................................8.21Figure 8.19 ACSELERATOR QuickSet Analog Output Settings ...............................................................8.22Figure 10.1 Factory Default AT String ....................................................................................................10.2Figure 10.2 DB-9 Connector Pinout for EIA-232 Serial Ports ................................................................10.4Figure 10.3 Ethernet Port Status LEDs....................................................................................................10.5Figure 10.4 Cables for Connecting the SEL-734 to a Computer .............................................................10.6Figure 10.5 Cable for Connecting the SEL-734 to a DNP Device ..........................................................10.7Figure 10.6 Cable for Connecting the SEL-734 to an External Modem..................................................10.7Figure 10.7 Cable for Connecting the SEL-734 to an

SEL-2020, SEL-2030, SEL-2032, SEL-2100, or another SEL-734 .................................10.7Figure 10.8 Using HyperTerminal to Read Settings ..............................................................................10.17Figure 10.9 Using HyperTerminal to Write Settings .............................................................................10.30Figure 10.10 Jumper Header—Password and Breaker Jumpers ..............................................................10.32Figure 11.1 Meter Front Panel .................................................................................................................11.1Figure 11.2 Default Display Screen .........................................................................................................11.2Figure 11.3 Front-Panel Pushbuttons .......................................................................................................11.3Figure 11.4 Access Level Security Padlock Symbol ...............................................................................11.3Figure 11.5 Password Entry Screen .........................................................................................................11.4Figure 11.6 Front-Panel Main Menu........................................................................................................11.6Figure 11.7 Main Menu > Meter Function ..............................................................................................11.6Figure 11.8 Meter Menu > Instantaneous Meter Display Functions .......................................................11.6Figure 11.9 Main Menu > Set/Show Function.........................................................................................11.7Figure 11.10 Set/Show > Meter Function ..................................................................................................11.7Figure 11.11 Set Meter > Port Function ....................................................................................................11.7Figure 11.12 Set/Show > Password Function ............................................................................................11.8Figure 12.1 Typical TEST Mode Connections for an SEL-734 Using a Single-Phase Test Source........12.4Figure 12.2 Typical TEST Mode Connections for an SEL-734 Using Three-Phase Test Source ...........12.4Figure C.1 SEL Communications Processor Star Integration Network .................................................. C.3Figure C.2 Multitiered SEL Communications Processor Architecture ................................................... C.4

xiList of Figures


Figure C.3 Enhancing Multidrop Networks With SEL Communications Processors..............................C.7Figure C.4 Example SEL Meter and SEL Communications Processor Configuration............................C.7Figure F.1 Example Decimal Enumeration ........................................................................................... F.31



Preface

Manual OverviewThe SEL-734 Advanced Metering System provides high-accuracy revenue metering and power quality metering for electric utilities and industrial applications. The SEL-734 has flexible, user-programmable SELOGIC® control equations that include mathematical functions. The metering and control functions are ideal for complete automation applications.

The SEL-734 Meter Instruction Manual describes common aspects of revenue meter application and use. It includes the necessary information to install, set, test, and operate the meter and more detailed information about settings and commands.

An overview of each manual section and topics follows.

Preface. This section describes the manual organization and the conventions used to present information.

Section 1: Introduction and Specifications. This section describes the basic features and functions of the SEL-734 Meter; lists the meter specifications.

Section 2: Installation. This section describes how to mount and wire the SEL-734 Meter, including connections for several applications; includes the SEL-734 front- and rear-panel diagrams.

Section 3: PC Software. This section describes how to use the ACSELERATOR QuickSet® SEL-5030 Software with the SEL-734.

Section 4: Metering. This section describes the operation of Instantaneous, Demand, Energy, Crest Factor, Maximum/Minimum Metering and Transformer/ Line Loss Compensation, Harmonic Monitoring, and Load Profile.

Section 5: Time-of-Use. This section describes the setup and use of the time-of-use features in the SEL-734.

Section 6: Power Quality and Event Analysis. This section describes the operation of Voltage Sag/Swell/Interruption Elements and standard 15-cycle event reports, 8 kHz event reports, Sequential Events Recorder (SER) reports, and Voltage Sag/Swell/Interruption (VSSI) reports.

Section 7: Time-Synchronized Measurements. This section explains theory and applications.

Section 8: Logic. This section describes the operation of optoisolated inputs IN101 through IN102 (models 0734ES2-XX and 0734ES2-6X) and IN401 through IN404 (reference model 0734ES2-6X); remote control switches (remote bit outputs RB01 through RB16); latch control switches (latch bit outputs LT01 through LT32); programmable timers (timer outputs SV01T through SV32T); math variables (math variable outputs MV01 through MV32); output contacts OUT101 through OUT103 (models 0734ES2-XX and 0734ES2-6X) and OUT401 through OUT404 (model 0734ES2-6X); rotating displays.

Section 9: Settings. This section explains how to enter settings and contains the following setting reference information: Meter Word bit table and definitions (Meter Word bits are used in SELOGIC control equation settings); Settings Sheets for general meter, SELOGIC control equation, global, SER, front-panel label, and communications port settings.

xiv


PrefaceConventions

Section 10: Communications. This section describes serial port connector pinout/terminal functions, communications cables, communications protocol, serial port commands, and Ethernet port commands.

Section 11: Front-Panel Operation. This section describes the front-panel operation of pushbuttons and correspondence to serial port commands and rotating displays.

Section 12: Testing and Troubleshooting. This section describes the general testing philosophy, methods, and tools, as well as meter self-tests and troubleshooting.

Appendix A: Firmware and Manual Versions. This appendix lists the present meter firmware version and details differences among the present and previous versions. Provides a record of changes made to the instruction manual since the initial release.

Appendix B: SEL Distributed Port Switch Protocol (LMD). This appendix describes how to perform settings and operation of the LMD to permit multiple SEL meters to share a common communications channel.

Appendix C: SEL Communications Processors. This appendix describes how SEL communications processors and PC software use SEL protocols optimized for performance and reliability.

Appendix D: Setting SELogic Control Equations. This appendix describes how to set the control elements (Meter Word bits) in the SELOGIC control equations.

Appendix E: Distributed Network Protocol. This appendix describes DNP and includes the DNP Port Settings Sheets.

Appendix F: Modbus RTU Communications Protocol. This appendix describes Modbus® RTU communications features supported by the SEL-734 Meter communications port.

Appendix G: Mirrored Bits Communications. This appendix contains a summary of MIRRORED BITS® settings and describes how MIRRORED BITS function with the SEL-734.

Appendix H: Analog Quantities. This appendix contains a summary of analog quantities available for use in load profile, displaying points, etc.

SEL-734 Meter Command Summary. This section briefly describes the serial port commands that are described in detail in Section 10: Communications.

ConventionsTypographic Conventions

There are three ways to communicate with the SEL-734:

➤ Using ACSELERATOR QuickSet Software.

➤ Using a command line interface on a PC terminal emulation window.

➤ Using the front-panel menus and pushbuttons.

The instructions in this manual indicate these options with specific font and formatting attributes. The following table lists these conventions.

xv


PrefaceSafety and General Information

Examples This instruction manual uses several example illustrations and instructions to explain how to effectively operate the SEL-734. These examples are for demonstration purposes only; the firmware identification information or settings values included in these examples may not necessarily match those in the current version of your SEL-734.

Safety and General InformationSafety Information

This manual uses three kinds of hazard statements, formatted as follows:

Hazardous Locations Approval

In North America, the meter is approved for Class 1 Division 2, Groups A, B, C, D, and T4 in the –40 to 70 degree Celsius range.

Symbols The following symbols from EN 61010-1 are often marked on SEL products.

Typographic Conventions

Example Description

STATUS Commands typed at a command line interface on a PC.

<Enter> Single keystroke on a PC keyboard.

<Ctrl+D> Multiple/combination keystroke on a PC keyboard.

Start > Settings PC dialog boxes and menu selections. The > character indicates submenus.

RESET Meter front-panel pushbuttons.

ENABLE Meter front- or rear-panel labels.

MAIN > METER Meter front-panel LCD menus and meter responses. The > character indicates submenus.

Indicates a potentially hazardous situation that, if not avoided, may result in minor or moderate injury or equipment damage.

! CAUTION ! WARNINGIndicates a potentially hazardous situation that, if not avoided, could result in death or serious injury.

Indicates an imminently hazardous situation that, if not avoided, will result in death or serious injury.

! DANGER

Symbol 14

Consult Documentation for Additional Information

Symbol 6

Protective (Safety) Ground Conductor Terminal

Symbol 1

Direct Current

Symbol 2

Alternating Current

Symbol 3

Direct and Alternating Current

Symbol 5

Earth (Ground) Terminal

!

xvi


PrefaceSafety and General Information

Use of controls or adjustments, or performance of procedures other than those specified herein, may result in hazardous radiation exposure.

This equipment has been tested and found to comply with the limits for a Class A digital device, pursuant to Part 15 of the FCC Rules. These limits are designed to provide reasonable protection against harmful interference when the equipment is operated in a commercial environment. This equipment generates, uses, and can radiate radio frequency energy and, if not installed and used in accordance with the instruction manual, may cause harmful interference to radio communications. Operation of this equipment in a residential area is likely to cause harmful interference in which case the user will be required to correct the interference at his own expense.

! FCC CLASS A CAUTION

Instructions for Cleaning and DecontaminationUse care when cleaning the SEL-734. Use a mild soap or detergent solution and a damp cloth to clean the chassis. Do not use abrasive materials, polish compounds, or harsh chemical solvents (such as xylene or acetone) on any surface.

Technical AssistanceObtain technical assistance from the following address:

Schweitzer Engineering Laboratories, Inc.2350 NE Hopkins CourtPullman, WA 99163-5603 USATelephone: +1.509.332.1890Fax: +1.509.332.7990Internet: www.selinc.comE-mail: [email protected]


Section 1Introduction and Specifications

OverviewThis section includes the following overviews of the SEL-734 Advanced Metering System:

➤ SEL-734 Meter Forms and Models

➤ Applications

➤ Hardware Connection Features

➤ Communications Connections

➤ Specifications

SEL-734 Meter Forms and ModelsThis instruction manual covers the following SEL-734 Meter Forms and Models.

Please see FOR Command (Change Meter Form) on page 10.29 for information on how to change the meter form. Model numbers are derived from the SEL-734 Model Option Table. For the available options, associated option codes, or to order an SEL-734, refer to the Model Option Table for this product at the SEL website.

The SEL-734 offers two options for current classes, CL10 or CL20. The internal hardware of the SEL-734 is identical for both classes. Therefore, a CL10 meter will meter accurately up to the CL20 meter rating of 20 amps. The only difference between an SEL-734 CL10 and CL20 is the configuration label on the front panel. SEL recommends using a CL20 meter unless a specification calls for a CL10 meter.

Throughout this manual, meter model 0734ES2-6X (Expansion Slot #2 = 6X) and model 0734ES2-8X (Expansion Slot #2 = 8X) are used to show the difference from model 0734ES2-XX (Expansion Slot #2 = XX) when necessary for discussion. The only difference is that meter models 0734ES2-6X and 0734ES2-8X have an extra I/O board (see Figure 2.9). Meter models 0734ES1-XX and 0734ES1-2X show the difference between an empty expansion slot #1 and slot #1 with an optional communications card.

Table 1.1 SEL-734 Form Numbers

Meter Form Type

Form 5 3 wire delta

Form 9 4 wire wye

1.2


Introduction and SpecificationsSEL-734 Meter Forms and Models

The SEL-734 is available with two different power quality and recording options. These features and their specifications are shown in Table 1.2.

Table 1.2 SEL-734 Feature Availability

Power Quality and Recording Option Standard: SEL-734 Advanced: SEL-734P

Available Memory 32 MB 128 MB

Load Profile Recorder

Channels 16 192

Recorders 1 12

Acquisition rates 1, 5, 10, 15, 30, 60 minutes 3–59 s, 1, 5, 10, 15, 30, 60 minutes

Storage at 5-minute intervals in days

12 Channels 770 2400

96 Channels N/A 280

Flicker Measurement N Y

Highest Harmonic Order 15th 50th

Waveform Event Reports

Storage capacity in events 64 16–3155

Event duration 0.25 s 0.25, 0.5, 1, 2, 5, or 10 s

Sample rate 1 kHz 1 kHz or 8 kHz

Sequential Events Recorder

Number of events >21,000 >21,000

Voltage Sag/Swell/Interruption Recorder

Typical number of summary events 60 60

Number of detailed rows >11,000 >11,000

Time-of-Use

Number of self-reads 15 15

1.3


Introduction and SpecificationsApplications

Applications

Figure 1.1 SEL-734 Applied at Billing Points Throughout the Power System

FeederMonitor

AuxiliaryLoads

ProcessLoads

Plant Net Input/Output

EthernetRemoteAccess

RemoteAccess

IndustrialLoad

Power ExchangeMonitoring

Contract BillReconciliation

G

G

Voltage and PowerQuality Monitoring

NET BillingWith Generator Control

Line Loadingand Phase AngleMeasurement

SEL-2030Communications

Processor

G

Unit Output

Local Monitoringand Control

CapacitorControl

Line and TransformerLoss Compensation

SEL-734

SEL-734

SEL-734

SEL-734

SEL-734

SEL-734SEL-734

SEL-734

SEL-734

SEL-734 SEL-734 SEL-734 SEL-734

SEL-734 SEL-734 SEL-734

1.4


Introduction and SpecificationsHardware Connection Features

Hardware Connection FeaturesSee Specifications on page 1.7 and Section 2: Installation for more information on hardware and connections.

Figure 1.2 SEL-734 Inputs, Outputs, and Communications Ports

i4155b

CT Boardq

q CT board not available with LEA option.

Ia, Ib, Ic, In

PT/LEA Board

Va, Vb, Vc, Vn

Ia, Ib, Ic, In

I/O Board

Expansion Slot #24 Inputs4 Outputs (solid-stateor electromechanical)or 4 Analog Outputs4 Solid-State Outputs

Comm Board

Expansion Slot #1EIA-485Telephone ModemEIA-232

Main BoardEthernetEIA-232 IRIG-BEIA-232 (Port 3 may be ordered as an EIA-485 port)

Power Supply Board2 Inputs3 Outputs

189-0395

1.5


Introduction and SpecificationsHardware Connection Features

Figure 1.3 SEL-734 Extra I/O Board (Expansion Slot #2)

Input/Output Board(Reference Model 0734ES2-6X)

Analog Output/Digital Output Board(Reference Model 0734ES2-8X)

1.6


Introduction and SpecificationsCommunications Connections

Communications ConnectionsSee Port Connector and Communications Cables on page 10.4 for more communications connection information.

Figure 1.4 SEL-734 Communications Connection Examples

ETHERNET CONNECTION

EIA-485 CONNECTIONS

SEL-734Meter(#1)

Computer

Port 4A/Port 3

Port 4A/Port 3

Port 4A/Port 3

SEL Communications Processor

SEL Communications Processor

Port 4C Port 4C

LOCAL CONNECTION

Port 1

(Metallic)CableC273A

Port 3 Port 2

DATA AND TIME-SYNCHRONIZATION CONNECTIONS

SEL-734Meter

MODEM CONNECTION

Port 4B

Connect to the SEL Communications ProcessorOnce and Communicate With Any Connected SEL Meter

Or...Connect to the SEL-734 MetersIndividually Via the Rear-Panel Serial Ports

SEL-734Meter

SEL-734Meter(#32)

SEL-734Meter(#2)

SEL-734Meter

SEL-734Meter

SEL-734Meter

SEL-734Meter

LAN

Cable C234

Fiber-Optic Cable #C800

FZST or #C800

FDST

SEL-2810

1.7


Introduction and SpecificationsSpecifications

Specifications``

General

AC Voltage Inputs

Meter Form 9 and Meter Form 5

Maximum Rating: 300 V continuous600 V for 10 seconds

Range:Revenue Accuracy120 V Option:240 V Option:

57–132 V132–277 V

Measurement120 V Option:240 V Option:

0–150 V0–300 V

Burden: 0.003 VA @ 120 V0.02 VA @ 240 V

Meter Form 9

300 VL-N, three-phase, four-wire (wye) connection

Meter Form 5

300 VL-L, three-phase, three-wire (delta) connection

25 V Low Energy Analog (LEA) Voltage Inputs

Burden: 10 MΩ

Range: 0.40–25 V

Accuracy at Power Factor 1.0: 0.2%, 0.4–25 V

Accuracy at Power Factor 0.5: 1.0%, 0.4–25 V

AC Current Signal Inputs (Current Transformer Inputs)

Measurement Category: II

IA, IB, IC Channels

Range:

CL10/CL20 Option: 0.15–20 A

CL2 Option: 0.010–6 A

Maximum Rating: 22 A continuous500 A for 1 second

Burden: ≤ 0.5 VA

Starting Load per ANSI C12.20:

CL10/CL20 Option: 10 mA

CL2 Option: 1 mA

Neutral Channel IN

Range:

CL10/CL20 Option: 0.15–2.5 A

CL2 Option: 0.010–0.75 A

Maximum Rating: 22 A continuous500 A for 1 second

Burden: ≤ 0.5 VA

12 V Low Energy Analog (LEA) Current Inputs

Burden: 1 MΩ

Range: 0.1–12.5 V

Accuracy at Power Factor 1.0:

2%, 0.1–1 V0.2%, 1–12.5 V


4.0%, 0.1–1 V0.3%, 1–12.5 V

150 V Low Energy Analog (LEA) Current Inputs

Burden: 10 MΩ

Range: 0.4–150 V


1%, 0.4–2 V0.2%, 2–150 V


1.5%, 0.4–2 V0.5%, 2–150 V

Frequency and Rotation

60/50 Hz system frequency must be specified at time of order. ABC/ACB phase rotation is user settable.

Frequency tracking range: 45 to 65 Hz(VA or VC required for frequency tracking).

Power Supply

Continuous Operating Limits

125/250 Volt Supply: 85–264 Vac (50/60 Hz)85–275 Vdc

24/48 Volt Supply: 19–58 Vdc

12/24 Volt Supply: 9.6–36 Vdc

VA Rating: <40 VA/15 W maximum<20 VA/7 W typical

Interruption (IEC 60255-11:1979)

100 ms at 250 Vac/Vdc50 ms at 125 Vac/Vdc

50 ms at 48 Vdc10 ms at 24 Vdc

Ripple (IEC 60255-11:1979): 5% for dc inputs

Terminal Voltage Dropout:

<40 V within 1 minute of power removal

Rated Insulation Voltage (IEC 60664-1:2002): 300 Vac

Dielectric Test Voltage: 2.8 Vdc

Rated Impulse Voltage (IEC 60664-1:2002): 4000 V

Output Contacts

Output ratings were determined with IEC 60255-23:1994, using the simplified method of assessment.

Standard (Electromechanical)

Make: 30 A per IEEE C37.90-1989

Carry: 3 A at 120 Vac, 50/60 Hz1.5 A at 240 Vac, 50/60 Hz

1 s Rating: 50 A

Make Rating: 3.6 kVA, Cos φ = 0.3

Break Rating: 360 VA, Cos φ = 0.3

Durability: >10,000 cycles at rated conditions

Pickup/Dropout Time: <35 ms

Maximum Operating Voltage (Ue): 250 V

Rated Insulation Voltage (Ui) (excluding EN 61010): 300 V

1.8



Breaking Capacity (10000 operations):24 Vdc 0.75 A L/R = 40 ms48 Vdc 0.50 A L/R = 40 ms125 Vdc 0.30 A L/R = 40 ms250 Vdc 0.20 A L/R = 40 ms

Cyclic Capacity (2.5 cycle/second):24 Vdc 0.75 A L/R = 40 ms48 Vdc 0.50 A L/R = 40 ms125 Vdc 0.30 A L/R = 40 ms250 Vdc 0.20 A L/R = 40 ms

Optional (Solid State): 100 mA continuous 250 Vac/Vdc operational voltage

Maximum On Resistance:

100 mAtypical: 50 Ωguaranteed: 75 Ω



Minimum Off Resistance: 10 MΩ

Pickup/Dropout Time: <25 ms

Analog Outputs

±1 mA Output

Current Range: ±1.2 mA

Minimum Output Impedance: 100 MΩ

Maximum Load: 10 kΩ

Accuracy: ±0.15% ±0.5 μA at 25°C

4–20 mA Output

Current Range: ±24 mA

Minimum Output Impedance: 100 MΩ

Maximum Load: 500 Ω

Accuracy: ±0.15% ±10 μA of full scale at 25°C

Optoisolated Input Ratings

DC Control Signal

250 Vdc: Pickup 200–275 VdcDropout 150 Vdc


125 Vdc: Pickup 100–137.5 VdcDropout 75 Vdc


48 Vdc: Pickup 38.4–52.8 VdcDropout 28.8 Vdc

24 Vdc: Pickup 15–30 VdcDropout <5 Vdc

12 Vdc: Pickup 9.6–13.2 VdcDropout <6 Vdc

AC Control Signal

250 Vac: Pickup 170.6–300 VacDropout 106 Vac

220 Vac: Pickup 150.3–264 VacDropout 93.2 Vac

125 Vac: Pickup 85–150 VacDropout 53 Vac

110 Vac: Pickup 75.1–132 VacDropout 46.6 Vac

48 Vac: Pickup 32.8–57.6 VacDropout 20.3 Vac

24 Vac: Pickup 14–27 VacDropout <5 Vac

AC mode is selectable for each input via Global settings IN101D–IN102D and IN401D–IN404D.

Current draw at nominal dc voltage: 2–6 mA, except for 220 Vdc and 250 Vdc (2 mA) and 24 Vdc (10 mA).

Time-Code Input

Meter accepts demodulated IRIG-B time-code input at EIA-232 Port 3, Port 2, or 2-pin Phoenix connector. Meter time is synchronized to within ±10 µs of time-source input.

Nominal Voltage: 5 Vdc +10%

Maximum Voltage: 8 Vdc

Synchronized Phasor Measurement

Max. Message Rate: 20 messages/second (Fnom = 60 Hz)10 messages/second (Fnom = 50 Hz)

Specification is with respect to MET PM command and SEL Fast Message Synchrophasor Protocol.

Voltage and Current Accuracy:

Fnom = 60 Hz ± 5 HzTVE = 1%

Fnom = 50 Hz ± 5 HzTVE = 1% for V1 and I1TVE = 1% + |50–F|/10% for VA, VB, VC, IA, IB, IC, VAB, VBC, VCA, IAB, IBC, and ICA

Frequency Accuracy: ± 5 mHz for Fnom ± 9 Hz

Operating Temperature

IEC 60068-2: –40° to + 85°C (–40° to +185°F)

Note: Not applicable to UL applications.

LCD: –20° to +70°C (–4° to +158°F)

Operating Environment

Pollution Degree:Overvoltage Category:

2II

Indoor Use

Maximum Altitude:Maximum Humidity:

2000 M95% RH

Weight

2.3 kg (5.0 lbs)

Dimensions

Refer to Figure 2.1 for meter dimensions.

Routine Dielectric Test

Current Inputs: 2.75 kVac for 1 s

Voltage Inputs: 2.2 kVac for 1 s

Optoisolated Inputsand Output Contacts: 2.2 kVac for 1 s

Power Supply: 3.11 kVdc for 1 s

EIA-485 Port: 1.5 kVdc for 1 s

IEC 60255-5:2000Dielectric tests performed on all units with the CE mark:

2200 Vdc for 1 s on EIA-485 communications port.

2000 Vac for 1 s on contact inputs, contact outputs, and analog inputs.

1.9



Terminal Connections

Rear Screw-Terminal Tightening Torque

Current Input Terminal Block (ring terminals are recommended)

Minimum: 0.9 Nm (8 in-lb)

Maximum: 1.4 Nm (12 in-lb)

Connectorized®

Minimum: 0.5 Nm (4.4 in-lb)

Maximum: 1.0 Nm (8.8 in-lb)

Connectorized terminals accept wire size 12–24 AWG.

User terminals or stranded copper wire should be at a minimum temperature rating of 105° C (221°F).

Processing Specifications

AC Voltage and Current Inputs

16 samples per power system cycle for instantaneous quantities.

8000 samples per second for rms quantities and harmonics.

3 dB low-pass filter cut-off frequency of 3000 Hz.

Control Processing

25 ms processing interval

SELOGIC Pickup and Accuracies

SELOGIC Timers: ±25 ms

Analog Values: ±3%

Timers

Pickup Ranges: 0.000–1000000.000 s, 25 ms steps

Pickup and Dropout Accuracy (for all timers): ±1 processing interval (25 ms)

Metering/MonitoringMetering Accuracy, One-Second Average (rms)

ANSI C 12.20 (1998) Accuracies are specified at 23°C and at nominal system frequency, nominal voltage, and nominal current unless noted otherwise.

Voltages VA, VB, VC: ± 0.15%

Voltages VAB,VBC, VCA: ± 0.15%

Currents IA, IB, IC: ± 0.15%

Current, Neutral IN: ± 1.0%

Frequency: ± 0.01 Hz

Energy (kWh), Imported/Exported Total: class 0.2

Peak Power Demand (kW): class 0.2

Power (kW) Total: class 0.2

Power (kW), per Phase: class 0.2

Reactive Energy (kVARh) Import/ Export per Phaseand Total: class 0.2

Apparent Energy (kVAh): class 0.2

Reactive Power (kVAR) per Phase and Total: class 0.2

Apparent Power (kVA) per Phase and Total: class 0.2

Reactive Power (kVAR) Peak Demand: class 0.2

Apparent Power (kVA) Peak Demand: class 0.2

Metering Accuracy, Instantaneous (25 ms)

Accuracies are specified at 23°C and at nominal system frequency unless noted otherwise.

Voltages VA, VB, VC: ±1%

Voltages VAB, VBC, VCA: ±1%

Currents IA, IB, IC: ±1%

Current, Neutral IN: ±2%

Frequency: ±0.01 Hz

Power (kW) per Phase and Total: ±2%

Reactive Power (kVAR) per Phase and Total: ±2%

Apparent Power (kVA) per Phase and Total: ±2%

Power Factor, at Unity PF: ±2%

Harmonic Accuracy per IEC 61000-4-7 (2002-08)

Quantity Condition Max Error for n ≤ 25Voltage UHn ≥ 1% UN 5% UHn

UHn < 1% UN 0.05% UNCurrent IHn ≥ 3% IN 5% IHn

IHn < 3% IN 0.15% INPower PHn > 150 W sec PHn • 5%

PHn < 150 W sec PHn ± 7.5 WNote: UN and IN are nominal voltage and current. UHn, IHn, and

PHn are nth order harmonic voltage, current, and power.UN = 120 V or 240 V (metering voltage option)IN = 0.5 A (CL2) or 5.0 A (CL10 and CL20)

THD and THDG: ±5% typical, ±10% worst case

K-Factor: ±5% typical, ±10% worst case

Distortion Power: ±3% typical, ±10% worst case

Flicker

PST: ±5% over the range 0.5–25 PST (10-min. interval)

PLT: ±5% over the range 0.5–25 PLT (2-hour interval)

Integration/Automation

Communications Ports

A total of five ports is available.

bps: 300 to 115200

Standard Ports

Optical (ANSI C12.18 Type 2): Front Panel

EIA-232: Rear Panel

Optional Ports

EIA-232/EIA-485/Modem: Rear Panel, 1.5 kVdc isolation

for EIA-485/Modem

10/100BASE-T Ethernet Port: Rear Panel

Fiber-Optic Ethernet Port

Wavelength: 1300 nm

Optical Connector Type: LC

1.10



Fiber Type: Multimode

Link Budget: 16.1 dB

Typical TX Power: –15.7 dBm

RX Min. Sensitivity: –31.8 dBm

Fiber Size: 62.5/125μm or 50/125μm

Approximate Range: ~6.4 Km

Data Rate: 100 Mb

Typical Fiber Attenuation:

–2 db/Km

Note: The EIA-232/EIA-485 Modem card functions as a single port, therefore, only one port is available at a time. The optional internal modem complies with Part 68 of the FCC Rules and Regulations.

Type Tests

Electromagnetic Compatibility Immunity

Surge Withstand Capability:

IEEE C37.90.1-2002 Elec. relays,2.5 kV oscillatory, 4 kV fast transient

IEC 60255-22-1:2007,2.5 kV peak common and2.5 kV peak differential mode1.0 kV peak common mode on communications ports

Surge Immunity: IEC 62052-11:2003,4 kV for Current, Voltage, and Power Supply Mains1 kV for Auxiliary Circuits

Power Frequency Magnetic Field Immunity:

IEC 61000-4-8:2009,1000 A/m for 3 seconds,100 A/m for 1 minuteexcludes optional modem

Pulse Magnetic Field Immunity: IEC 61000-4-9:1993, 1000 A/m

ElectrostaticDischarge Immunity:

IEC 61000-4-2:2008Elec. disturb., Section 2: ESD,Severity Level: 4

IEC 60255-22-2:2008Elec. disturb. Section 2: ESD,Severity Level:4; both polarities at Levels 1, 2, 3, and 4

Radiated RadioFrequency Immunity:

IEC 61000-4-3:2010,Severity Level: X (15 V/m)

IEC 60255-22-3:2007 Elec. relays, Section 3: Radiated electromagnetic field disturb.,Severity Level: 3 (10 V/m)

ANSI C12.20 (1998),Severity Level: 15 V/m

Conducted RadioFrequency Immunity:

IEC 61000-4-6:2008,Severity Level: 3

Fast TransientBurst Immunity:

IEC 61000-4-4:2011,Severity Level: 4

Environmental Tests

Cold: IEC 60068-2-1, 2007Envir., Test Ad,Severity: 16 hours at –40°C

Dry Heat: IEC 60068-2-2:2007,Envir., Part 2: Test Bd,Severity: 16 hours at +85°C

Damp Heat, Cyclic: IEC 60068-2-30:2005Basic envir., Part 2: Test Db,Severity: 25° to 55°C, 6 cycles, 95% humidity

Enclosure Protection: IEC 60529:2001, IP65, enclosed in panel with available gasket (P/N: 915900097); IP41 without gasket; IP20 for rear panel

Vibration, Shock, and Bump:

IEC 60255-21-1:1988 Elec. relays, Part 21: Vibration, shock, bump, and seismic, Section 1,Severity: Response: Class 2Endurance: Class 1

IEC 60255-21-2:1988 Elec. relays, Part 21: Vibration, shock, bump, and seismic, Section 2,Severity: Response: Class 2Endurance: Class 1

IEC 60255-21-3:1993 Elec. relays, Part 21: Vibration, shock, bump, and seismic, Section 3,Severity: Class 2

Safety

DielectricStrength/Impulse:

IEC 60255-5:2000 Elec. relays, Part 5: Insulation, Section 6:2.5 kVac on AC current inputs,contact inputs, and contact outputs, 3.1 kVdc on power supply, and 2.2 kVdc on EIA-485 port for 60 sec. dielectric, Severity: 2500 Vac on analog inputs, contact inputs, and contact outputs; 3100 Vdc on power supply

IEC 60255-5:20000.5 Joule, 5 kV on power supply,contact inputs, contact outputs, ac current inputs, and voltage inputsSection 8: Impulse Voltage, 2200 Vdc on EIA-485, Severity Level: 0.5 Joule, 5 kV

High-VoltageLine Surges:

IEEE C62.41-1991100 kHz Ring Wave for Location Category B3, Peak Voltage of 6 kV and Short-Circuit Peak Current of 3 kA 1.2/50 μs Combination Wave for Location Category B3, Peak Voltage of 6 kV and Short-Circuit Peak Current of 3 kA

Impulse Voltage Test: IEC 687:1992–066 kV on power supply, ac current inputs, and voltage inputs

CertificationsISO 9001: This product was designed and manufactured under an

ISO 9001 certified quality management system.

ANSI C12.20:2002; class 0.2, CL2, and CL10/CL20Radiated Emissions: FCC Part 15; Class A

IEC 62053-22:2003; class 0,2 S

IEC 62052-11; rack-mounted meters

IEC 62053-23:2003; class 0,2 S

C22.2 No. 61010-04

C22.2 No. 142

UL 508

ERCOT Compliant

CFG G0000-48-1999 Compliant per LAPEM

CE: Mark–EMC Directive, Low Voltage Directive

Note: Optional modem not CE compliant.


Section 2Installation

OverviewThis section provides information you need to install the SEL-734 Meter, including the following topics:

➤ Meter Mounting

➤ Rear-Panel Connection Diagrams

➤ Making Rear-Panel Connections

➤ Circuit Board Connections

Meter MountingFigure 2.1 through Figure 2.3 give the SEL-734 Meter dimensions for the panel-mount applications.

For rack, wall, retrofit, and outdoor mounting options see the SEL-734 Model Option Table on the SEL website or contact your local SEL sales representative.

Figure 2.1 SEL-734 Horizontal Panel-Mount Dimensions

Torque the mounting screws to a least 12 in-lb, but no more than 15 in-lb.

2.2


InstallationMeter Mounting

Figure 2.2 SEL-734 Vertical Panel-Mount Dimensions

Figure 2.3 SEL-734 Easily Extractable Meter (EXM) Mounting Dimensions

Figure 2.4 details the SEL-734T meter dimensions for the panel-mount applications. The SEL-734T is normally mounted with the front panel facing the mounting surface, allowing access to the rear-panel connections.

2.3


InstallationConnection Diagrams

Figure 2.4 SEL-734T Panel-Mount Dimensions

Physical Location You can mount the SEL-734 in a sheltered indoor environment (a building or an enclosed cabinet) that does not exceed the temperature and humidity ratings for the meter. For voltage and current inputs, the SEL-734 is rated for Measurement Category II, (CAT II) and Pollution Degree 2. This rating allows mounting of the meter indoors or in an outdoor (extended) enclosure where the meter is protected against exposure to direct sunlight, precipitation, and full wind pressure, but neither temperature nor humidity are controlled. You can place the meter in extreme temperature and humidity locations. The temperature range over which the meter operates is –40° to +80°C (–40° to +176°F). The meter operates in a humidity range from 5 percent to 95 percent, no condensation. The power supply supports voltage fluctuations up to ±10 percent of nominal voltage. For IEC 61010 certification, the SEL-734 rating is 2000 meters (6560 feet) above mean sea level.

Connection DiagramsFigure 2.5 and Figure 2.6 represent an example of meter configurations. All units can be ordered with an extra I/O or communications card. For model options, view the SEL-734 Model Option Table on the SEL website or contact your local SEL sales representative.

2.4



Figure 2.5 SEL-734 Horizontal Front-Panel Drawing

i3618c

2.5



Figure 2.6 SEL-734 Vertical Front-Panel Drawing

i4164b

2.6



Figure 2.7 and Figure 2.8 show the front panels of the SEL-734B and SEL-734T meters.

Figure 2.7 SEL-734B Front Panel

Figure 2.8 SEL-734T Front Panel

i4945a

2.7



Figure 2.9 and Figure 2.10 show typical side and rear panels of SEL-734 models. Your meter configuration may be different. Please refer to www.selinc.com for the drawing specific to your meter.

Figure 2.9 Side- and Rear-Panel Drawings for Typical Meters With CT Inputs

i4163a

i4155a

http://www.selinc.com/

2.8



Figure 2.10 Side- and Rear-Panel Drawings for Typical Meters With LEA Inputs

2.9


InstallationMaking Rear-Panel Connections

Making Rear-Panel ConnectionsRefer to Figure 2.12 and Figure 2.13 for wiring examples of typical applications.

Refer to Figure 2.9 for rear-panel connections and component location.

Required Equipment You will need the following equipment to install SEL-734 rear-panel connections:

Tools: 1/4" (6 mm) slotted-tip screwdriver for current inputs; 5/32" x 1/32" (4 mm x .8 mm) slotted-tip screwdriver for Connectorized® terminal blocks. See recommended torque settings and wire sizes in Specifications on page 1.7.

Chassis Ground (Earthing)

Ground the meter chassis at the ground terminal located on the rear of the meter.

You must connect the ground terminal labeled GND on the rear of the panel to a rack frame or switchgear ground for safety and performance. Use 10 AWG (6 mm2) to 12 AWG (4 mm2) less than 2 m (6.6 feet) in length for the ground connection.

Figure 2.11 Grounding Terminal Symbol

Power Supply Follow these steps to connect power to the SEL-734:

Step 1. Connect the control voltage to the POWER terminals.

Step 2. Apply power to the meter.

➢ Refer to Section 1: Introduction and Specifications for power supply ratings. The meter power supply rating is listed on the serial number sticker on the left side of the meter.

➢ The terminals labeled POWER on the rear panel (A01[+] and A02[–]) must connect to a power source that matches the power supply characteristics that your SEL-734 specifies on the rear-panel serial number label.

➢ The POWER terminals are isolated from chassis ground. Use 12 AWG (4mm2) to 16 AWG (1.5 mm2) size to connect to the POWER terminals. Connection to external power must comply with IEC 60947-1 and IEC 60947-3.

Step 3. Place an external switch or circuit breaker in the POWER leads for the SEL-734. This disconnect device must interrupt both the hot (H) and neutral (N) power leads.

The maximum current rating for the power disconnect circuit breaker or optional overcurrent device (fuse) must be 20 A. Be sure to locate this device within 3.0 m (9.8 feet) of the meter. Operational power is internally fused by power supply fuse F1.

GND

NOTE: The polarity indicators on terminals A01(+) and A02(–) control power passes through the POWER terminals to a fuse and to the switching power supply. The control power circuitry is isolated from the meter chassis ground.

2.10



Step 4. The circuit breaker (or equivalent approved disconnect device appropriate for the country of origin) must comply with IEC 60947-1 and IEC 60947-3 and be identified as the disconnect device for the equipment.

Table 2.1 lists the SEL-734 power supply fuse requirements. Be sure to use fuses that comply with IEC 60127-2. Note that the power supply range covers two widely used nominal input voltages. The SEL-734 power supply operates from 45 Hz to 65 Hz when ac power is used for the POWER input.

The SEL-734 accepts dc power input where the 125/250 Vdc supply also accepts 120/240 Vac.

When connecting a dc power source, you must connect the source with the proper polarity, as indicated by the + (terminal A01) and — (terminal A02) symbols on the power terminals. When connecting an ac power source, A01 is hot (H), and A02 is neutral (N).

The SEL-734 internal power supply exhibits low power consumption and a wide-input voltage tolerance.

Power Supply Fuse ReplacementYou can replace a blown or failed fuse in an SEL-734 power supply, or you can return the SEL-734 to the SEL factory for fuse replacement. If you decide to replace the fuse, perform the following steps to replace the power supply fuse:

Step 1. De-energize the meter.

Step 2. Remove any cables connected to communications ports on the rear panels.

Step 3. Loosen the eight rear-panel screws, and remove the meter rear panel.

Step 4. Locate the fuse on the power supply board.

Each circuit board corresponds to a row of rear-panel terminal blocks. SEL-734 model 0734ES2-XX has only a main board, CT board, PT board, and power supply. Model 0734ES2-6X has an extra I/O board in addition to the other boards. Models 0734ES2-XX and 0734ES2-6X may also have an optional communications board.

Step 5. Replace the fuse.

Step 6. When you are finished, slide the printed circuit board (PCB) into the meter chassis. Replace the meter rear-panel cover.

Table 2.1 SEL-734 Power Supply Fuse Requirements

Nominal Power Supply Voltage

Rating

Power Supply Voltage Range

Fuse F1Fuse

DescriptionModel

Number

12/24 Vdc 12-24 Vdc

T3.15AH250V

5 x 20 mm, time-lag, 3.15 A,

high break capacity,

250 V

Bussmann S505-3.15A or SCHURTER

SPT 0001.2509

24/48 Vdc 24–48 Vdc

110/120/220/240 Vac

110/125/220/250 Vdc

110–240 Vac (45–65 Hz)

110–250 Vdc


! DANGER


! CAUTION


! DANGER

Have only qualified personnel service this equipment. If you are not qualified to service this equipment, you can injure yourself or others, or cause equipment damage.

! WARNING

2.11



Step 7. Replace any cables previously connected to communications ports.

Step 8. Reenergize the meter.

Output ContactsModel 0734ES2-XX

Model 0734ES2-XX can be ordered with standard output contacts only (two Form A and one Form C). Refer to Specifications on page 1.7 for output contact ratings.

Standard output contacts are not polarity dependent. Solid state contacts are recommended for KYZ operation to prevent mechanical wear.

Models 0734ES2-6X and 0734ES2-8XModels 0734ES2-6X and 0734ES2-8X have output contacts on the following boards:

➤ Power Supply Board: OUT101 through OUT103 (ordered as standard output contacts only)

➤ Extra I/O Board: OUT401 through OUT404 (ordered as standard or solid state output contacts on the 6X option; solid state only on the 8X option)

Refer to Specifications on page 1.7 for output contact ratings.

Analog OutputModel 0734ES2-8X and 0734ES2-9X

Model 0734ES2-8X has four user-configurable 0–1 mA analog outputs located on the extra I/O board. Model 0734ES2-9X has four user-configurable 4–20 mA analog outputs located on the extra I/O board. Refer to Specifications on page 1.7 for analog output ratings.

Optoisolated Inputs The optoisolated inputs in any of the SEL-734 models (e.g., IN102, IN404) are not polarity dependent. With nominal control voltage applied, each optoisolated input draws between 2–6 mA of current. Refer to Specifications on page 1.7 for optoisolated input ratings.

Inputs can be configured to respond to ac or dc control signals via global settings IN101D–IN102D and IN401D–IN404D.

Refer to the serial number sticker on the meter rear panel for the optoisolated input voltage rating (listed under label LOGIC INPUT).

Current Transformer Inputs

Note the polarity markings above terminals Z01 through Z08. Refer to Figure 2.12 and Figure 2.13 for typical CT wiring examples.

Refer to the part number on the meter front panel for the nominal current class rating for the phase (IA, IB, IC) and neutral (IN) current inputs.

2.12



Potential Transformer Inputs

Note the signal labels (VA, VB, VC) on terminals E01 through E04.

Determining the Voltage Input RatingThe serial number sticker on the meter rear panel indicates the continuous voltage input rating. The part number also contains the voltage rating information.

This voltage rating applies to the three-phase voltage inputs (VA-N, VB-N, VC-N). The voltage rating is in units of VL-N when the meter is Form 9 (three-phase, four-wire), or VL-L when the meter is Form 5 (three-phase, three-wire). The following two subsections explain the Form 5 and Form 9 voltage input connections.

Form 9 VoltagesAny of the single-phase voltage inputs (i.e., VA-N, VB-N, or VC-N) can be connected to voltages up to 150 V continuous for 120 V meters and 300 V continuous for 240 V meters. Figure 2.12 shows an example of Form 9-connected voltages. Frequency is determined from the meter voltage terminals VA-N and VC-N.

Form 9 Example

Figure 2.12 Form 9, 3-Element, 4-Wire Wye

NOTE: “3V0” in the MET command (via serial port or front panel) is derived internally from the VA, VB, and VC voltage inputs.

N

C

B

LINE

LOAD

A

B

C

3-Phase4-Wire Wye

A

01

02

03

04

E

01

02

03

04

05

06

07

08

Z

N

C

B

A

500

SEL-734 Current Inputs SEL-734 Voltage Inputs

2.13



Form 5 VoltagesPhase-to-phase voltage (up to 150 V continuous for 120 V meters and 300 V continuous for 240 V meters) can be connected to voltage inputs VA-VB and VB-VC when the meter is connected as shown in Figure 2.13.

Referring to Figure 2.13, you can see that the meter interprets the voltage signal detected across the VA-N terminals as VAB and the voltage signal detected across the VC-N terminals as VCB (or –VBC). Phase-to-phase voltage VCA is derived internally with the equation VCA = VCB – VAB (meter ignores the voltage at the VB terminal). Event reports are the only means by which signals applied to meter voltage terminals VA-N, VB-N, and VC-N can be directly observed. Frequency is determined from the meter voltage terminals VA-N and VC-N.

Form 5 Example

Figure 2.13 Form 5, 2-Element, 3-Wire Delta

The meter will use voltage VAB as the phase angle reference (zero degrees) when a sufficient voltage signal is present (13 V secondary).

Serial Ports Refer to Table 10.1 for information on the serial ports available on the different SEL-734 models. All ports (1, 2, 3, and 4) are independent; therefore, you can communicate to any combination simultaneously.

Serial Port 4 on all SEL-734 models with optional communication card consists of an EIA-485 (4A), telephone modem (4B), and an EIA-232 (4C) port. Only one port is available at a time via a port setting.

Internal Modem The SEL-734 optional internal modem complies with Part 68 of the FCC Rules and Regulations. The SEL-734 has a label that contains the FCC

A

B

C

3-Phase3-Wire Delta

C

B LINE

LOAD

A

01

02

03

04

E

01

02

03

04

05

06

07

08

Z

C

B

A

500

SEL-734 Current Inputs SEL-734 Voltage Inputs

2.14



Registration Number and Ringer Equivalence Number (REN) of the modem. You must, upon request, provide this information to your telephone company.

The REN is useful in determining the quantity of devices you can connect to a telephone line and still have all of these devices ring when the number is called. In most areas, the sum of the RENs of all devices connected to one line should not exceed five. To determine the number of devices you can connect to the line, contact your local telephone company to find the maximum REN for your calling area.

If your system causes harm to the telephone network, the telephone company may discontinue service temporarily. If possible, they will notify you in advance. If advance notification is not practical, you will be notified as soon as possible. Your telephone company may make changes in its facilities, equipment, operations, or procedures that could affect proper functioning of your equipment. If they do, they should notify you in advance to give you an opportunity to maintain uninterrupted telephone service.

The serial PORT 4 EIA-485 plug-in connector accepts wire size AWG 24 through 12. Strip the wires 8 mm (0.31 inches) and install with a small slotted-tip screwdriver.

EIA-232 Cables All EIA-232 ports accept 9-pin D-subminiature male connectors. EIA-232 PORT 3 and PORT 2 on all the SEL-734 models includes the IRIG-B time-code signal input (see the following discussion on IRIG-B Time-Code Input on page 2.15 and Table 10.5).

The pin definitions for all the ports are given on the top panel and detailed in Table 10.5 through Table 10.7.

Refer to Table 2.2 for a list of cables available from SEL-734 for various communication applications. Refer to Section 10: Communications for detailed cable diagrams for selected cables (cable diagrams precede Table 10.7).

For example, to connect any EIA-232 port to the 9-pin male connector on a laptop computer, order SEL Cable C287 and specify the length needed (standard length is eight feet). Order SEL Cable C273A to connect the SEL-734 Meter EIA-232 PORT 3 to the SEL-2032, SEL-2030, or SEL-2020 Communications Processor that supplies the communication link and the IRIG-B time synchronization signal.

Ruggedized Cables SEL offers a ruggedized version of many of our standard communication cables. Ruggedized cables feature metal connector shells and improved shielding, that reduce bit errors during EMC events. These cables offer greater communications reliability in electrically noisy environments.

For connecting devices at distances over 100 feet, where metallic cable is not appropriate, SEL offers fiber-optic transceivers. The SEL-2800 family of transceivers provides fiber-optic links between devices for electrical isolation and long-distance signal transmission up to 80 km. Contact SEL for further information on these products.

2.15



IRIG-B Time-Code Input

The SEL-734 accepts a demodulated IRIG-B time signal to synchronize the internal clock with an external source. Two options for IRIG-B signal input are given, but only one should be used at a time. IRIG-B (01 and 02) inputs or an SEL communications processor via serial EIA-232 PORT 3 and PORT 2 may be used (see Table 10.5 and Figure 10.7). The available communications processors are the SEL-2032, SEL-2030, SEL-2020, and the SEL-2100 Logic Processor (see Table 2.2).

Ethernet Port The SEL-734 can be ordered with an optional 10/100BASE-T or 100BASE-FX Fiber-Optic Ethernet port (PORT 1). You can connect to PORT 1 of the meter using a standard RJ-45 connector with the copper Ethernet or a standard LC connector with the fiber-optic Ethernet. The Ethernet port supports a total of six simultaneous sessions (see Ethernet on page 10.4).

EIA-232 (Port 2) PORT 2 is identical to EIA-232 PORT 3.

Optical Port The front-panel optical port complies with the power requirements of C12.18 Protocol Specification for ANSI Type 2 Optical Ports. You can communicate with the meter using an ANSI C12.18 optical probe.

SEL has tested a variety of optical probes for compatibility with the SEL-734. Table 2.3, although not exhaustive, can be used as a guide for selecting compatible probes.

Table 2.2 Communication Cables Used to Connect the SEL-734 to Other Devices

SEL-734 EIA-232 Serial Ports

Connect to DeviceSEL Standard

Cable No.SEL Ruggedized

Cable No.

All EIA-232 ports PC, 25-Pin Male (DTE) C227A C227R

All EIA-232 ports Laptop PC, 9-Pin Male (DTE) C287 C287R

EIA-232 PORT 3 SEL-2032/2030/2020/2100 without IRIG-B C272A C272R

EIA-232 PORT 3 SEL-2032/2030/2020/2100 with IRIG-B C273A C273R

All EIA-232 ports Standard Modem, 25-Pin Female (DCE) C222 C222R

Front Optical Port ANSI C12.18 Optical Probe C660/C661 n/a

Table 2.3 Optical Port Probes (Sheet 1 of 2)

SEL-734 Compatible Optical Probes

Connector Special Instructions

ABACUS ELECTRICS A6Z

(SEL part number C660)

DB-9 None

ABACUS ELECTRICS A7Z DB-9 DTR Off

ABACUS ELECTRICS A9U

(SEL part number C661)

USB DTR Off; requires software driver

RTS On

RTS/CTS Off

ABB Unicom III DB-9 DTR Off

GE SmartCoupler SC-1A DB-9 DTR Off

Microtex Electronics FR3 USB Maximum 19200 baud rate; requires software driver

NOTE: The Optical Port is not available on SEL-734T and SEL-734B models.

2.16


InstallationCircuit Board Connections

Internal Telephone Modem

The SEL-734 can be ordered with an optional communications card. PORT 4B of this optional card is an internal telephone modem. Connect to the modem using a standard telephone cable and RJ-11 jack.

Sealing Front-panel password protection seals the SEL-734 electronically. Any operator can view meter data and settings, but a password is necessary to reset or edit any field (see Front-Panel Security on page 11.3). Rear-panel anti-tamper seals less than .095 inches in diameter (see Figure 1.2) provide evidence of unauthorized access to the meter interior.

Cleaning Use care when cleaning the SEL-734. Use a mild soap or detergent solution and a damp cloth to clean the chassis. Do not use abrasive materials, polishing compounds, or harsh chemical solvents (such as xylene or acetone) on any surface.

Circuit Board ConnectionsAccessing the Meter Circuit Boards

To replace the clock battery on the meter main board, refer to Figure 2.14 and take the following steps:

Step 1. De-energize the meter.

Step 2. Remove any cables connected to communications ports on the rear panels.

Step 3. Loosen the eight rear-panel screws, and remove the meter rear panel.

Each circuit board corresponds to a row of rear-panel terminal blocks. SEL-734 model 0734ES2-XX has only a main board, CT board, PT board, and power supply. Model 0734ES2-6X has an extra I/O board in addition to the other boards. Models 0734ES2-XX and 0734ES2-6X may also have an optional communications board.

Step 4. Locate the battery (refer to Figure 2.14) and replace it.

Step 5. Slide the printed circuit board (PCB) into the meter chassis.

Step 6. Replace the meter rear-panel cover.

Step 7. Replace any cables previously connected to communications ports.

Step 8. Reenergize the meter.

P+E Technik K01-USB USB Requires software driver

Cannot use to upgrade firmware

uData Net PM500-300 DB-9 DTR Off; requires power from ac adap-tor or connector for mouse or keyboard

Table 2.3 Optical Port Probes (Sheet 2 of 2)

SEL-734 Compatible Optical Probes

Connector Special Instructions


! CAUTION

2.17


InstallationCircuit Board Connections

Figure 2.14 Connector and Major Component Locations on the SEL-734 Main Board (Models 0734ES2-XX and 0734ES2-6X)

Clock Battery Refer to Figure 2.14 for clock battery location (front of main board). At room temperature (25°C), a battery will nominally operate for 10 years at rated load. The battery powers the meter clock (date and time) if the external power source is lost or removed. Therefore, the battery life can extend beyond the nominal 10 years if the meter is powered.

The battery is a 3 V lithium coin cell and cannot be recharged. The battery voltage can be checked using the STA command (see Section 10: Communications). The SEL-734 generates a warning when the battery voltage is less than 2.3 Vdc.

If the meter does not maintain the date and time after power loss, replace the battery. Follow the instructions in Accessing the Meter Circuit Boards on page 2.16 to remove the meter main board.

Remove the battery from beneath the clip and install a new one. The positive side (+) of the battery faces up. Reassemble the meter as described in Accessing the Meter Circuit Boards. Set the meter date and time via serial communications port (see Section 10: Communications).

EthernetPort

IRIG-B

EIA-232Port

EIA-232Port

Battery

There is danger of explosion if the battery is incorrectly replaced. Replace only with Ray-O-Vac® no. BR2335 or equivalent recommended by manufacturer. Dispose of used batteries according to the manufacturer’s instructions.

! CAUTION



Section 3PC Software

OverviewEach SEL-734 Meter includes the ACSELERATOR QuickSet® SEL-5030 Software program which allows meter configuration, monitoring, testing, and data retrieval. ACSELERATOR QuickSet offers the following capabilities:

➤ Create and manage device settings with a Windows® interface.

➤ Store and retrieve settings.

➤ Upload and download device settings files to and from meters.

➤ Analyze power system events with integrated waveform and harmonic analysis tools.

➤ Export Load Profile and VSSI data to .HHF or .CSV format.

➤ Monitor real-time and stored power system data.

➤ Control the device using command operations through a graphical interface environment and execute serial port commands in the terminal mode.

➤ Configure the communications port and passwords.

InstallationTo install ACSELERATOR QuickSet, perform the following steps.

Step 1. Close all other software applications on the PC.

Step 2. Insert the ACSELERATOR QuickSet SEL-5030 software CD into the PC CD-ROM drive. The installation program should start automatically. If the installation program does not start, select Run from the Windows Start menu and type the following command: D:\SETUP (substitute D:\ with the PC CD-ROM drive letter).

Step 3. Follow the steps that appear on the screen. The installation program will perform all the necessary steps to load ACSELERATOR QuickSet onto the PC.

3.2


PC SoftwareStarting ACSELERATOR QuickSet

Starting ACSELERATOR QuickSetYou can start ACSELERATOR QuickSet in the following ways:

Step 1. Double-click the ACSELERATOR QuickSet icon if you have a desktop shortcut.

Step 2. Choose Programs > SEL Applications and select the ACSELERATOR QuickSet icon to start the program.

ACSELERATOR QuickSet Design TemplatesLicensed ACSELERATOR QuickSet versions allow you to create personalized templates for specific applications. Use ACSELERATOR QuickSet design templates within ACSELERATOR QuickSet to implement such various schemes as capacitor bank controls. ACSELERATOR QuickSet design templates hide settings you do not want to change (e.g., SELOGIC control equations), while making visible the minimum necessary settings (e.g., timer and pickup settings) to implement the scheme. All settings can use aliases and allow mathematical manipulation for simple end-user interfacing. Create ACSELERATOR QuickSet design templates that include the most commonly used meter features and settings for your application.

The meter stores ACSELERATOR QuickSet design templates on the meter, ensuring that users connecting with different computers will retrieve the correct template.


Section 4Metering

OverviewThis section explains the following SEL-734 Meter metering functions:

➤ Four-Quadrant VAR Metering

➤ Instrument Transformer Compensation

➤ Instantaneous Metering

➤ Demand Metering

➤ Energy Metering

➤ Energy Interface

➤ Maximum/Minimum Metering

➤ Crest Factor Metering

➤ Harmonic Metering

➤ Transformer/Line Losses

➤ Load Profile Report

➤ Metering Calculations

4.2


MeteringFour-Quadrant VAR Metering

Four-Quadrant VAR MeteringThe SEL-734 calculates four-quadrant voltampere reactive (VAR) values following the IEEE VAR sign convention as illustrated in Figure 4.1. Appendix H: Analog Quantities lists each four-quadrant VAR reported by the meter.

Figure 4.1 IEEE VAR Sign Convention

The SEL-734 displays VARs in four separate quadrants I–IV: IN/Delivered-Lagging (I), IN/Delivered-Leading (II), OUT/Received-Lagging (III), and OUT/Received-Leading (IV). The notations, IN and OUT, used by the SEL-734 are synonymous with delivered and received as shown in Figure 4.2.

Figure 4.2 SEL-734 Power Flow Notations

Four-Quadrant Meter Word Bits

In addition to displaying analog VAR quantities in all four quadrants, Meter Word bits describing the instantaneous VAR quadrants are available (see Meter Word Bits (Used in SELogic Control Equations) on page 9.2). These bits are useful when monitoring unsigned VARs.

(+) Reactive

(—) Reactive

(+) ActiveEnergy

Delivered

(—) ActiveEnergy

Received

Quadrant Power Factor Watts VarsIIIIIIIV

Lag

LagLead

Lead

Delivered (+)

Delivered (+)

Received (–)Received (–)

Delivered (+)Delivered (+)Received (–)Received (–)

θ Lagging

θ Lagging

θ Leading

θ Leading

III IV

III

SEL-734

Source

(Electric Utility)

Load

(Industrial Plant)

OUT (Received)

IN (Delivered)

4.3


MeteringInstrument Transformer Compensation

Instrument Transformer CompensationIdeal instrument transformers produce a secondary signal in ratio and in phase with the primary signal. In reality, instrument transformers normally cause a ratio and phase shift in the secondary signal. Instrument Transformer Compensation (ITC) in the SEL-734 compensates the sampled values, affecting all metered quantities.

Different types of instrument transformers shift the phase by different amounts. For example, Rogowski coils typically shift the phase linearly, while current transformers shift the phase nonlinearly. To account for these differences, the SEL-734 allows you to program six calibration points, each with a unique phase angle measurement and ratio correction factor. You may elect to use only one calibration point or all six.

When you program the SEL-734 with one calibration point, the meter applies the correction factors across the entire range of applied signals. If you program more than one point, the SEL-734 linearly interpolates based on the applied signal to determine which correction factors it should use. If the measured value lies below the calibration points, the SEL-734 uses the lowest calibration point values. If the measured value lies above the calibration points, the SEL-734 uses the highest calibration point values.

You may compensate instrument transformers on each phase with different ratio correction factors and phase angle measurements. To configure the SEL-734 for ITC, first test the instrument transformer and record the ratio correction factors and phase angle measurements at each calibration point. Next, enable ITC and configure the number of calibrations points desired. Lastly, program the ITC settings recorded from the instrument transformer test.

The Ratio Correction Factor setting cancels out the ratio error associated with the instrument transformer. For example, if you apply 100 primary amps to a 100:1 current transformer and you measure 0.925 secondary amps, the ratio correction factor is 1.081. You may use the following equation to determine the proper Ratio Correction Factor setting.

The Phase Angle Minutes setting cancels out the phase error associated with the instrument transformer. For example, if you apply primary current with a zero degree phase angle reference and you measure the secondary current with a 1 degree leading phase angle, you should set the Phase Angle Minutes setting to 60 minutes. You may use the following equation to determine the proper Phase Angle Minutes setting.

For example, assume you test a current transformer with a CTR of 100:1 and find the results as shown in Table 4.1.

RCFSecondary Test Current

Measured Secondary Current--------------------------------------------------------------- Primary Test Current

Measured Secondary Current CTR• -----------------------------------------------------------------------------------------==

PAM Secondary Phase Angle Primary Phase Angle–( ) 60 minutes1 degree

--------------------------• =

4.4



Configure the following settings as shown to correct for inaccuracies in this instrument (where x is the phase A, B, or C):

EITCI := 6

ICALx_1 := 1.00

IRCFx_1 := 1.1765

IPAMx_1 := 1530

ICALx_2 := 10.00

IRCFx_2 := 1.0256

IPAMx_2 := 480

ICALx_3 := 30.00

IRCFx_3 := 1.0076

IPAMx_3 := 72

ICALx_4 := 50.00

IRCFx_4 := 1.0101

IPAMx_4 := 30

ICALx_5 := 100.00

IRCFx_5 := 1.0050

IPAMx_5 := –6

ICALx_6 := 200.00

IRCFx_6 := 0.9926

IPAMx_6 := –60

Figure 4.3 shows the Ratio Correction Factor vs. the calibration point of the CT example given.

Table 4.1 Example Current Transformer Test Data

Test Data

Calibration Point n 1 2 3 4 5 6

Test Load (amps, primary) 1.0000 10.0000 20.0000 50.0000 100.0000 200.0000

Measured Load (amps, secondary) 0.0085 0.0975 0.1985 0.4950 0.9950 2.0150

Phase Angle Error (degrees) 25.50 8.00 1.20 0.50 –0.10 –1.00

SEL-734 Settings

Ratio Correction Factor 1.1765 1.0256 1.0076 1.0101 1.0050 0.9926

Phase Angle Minutes 1530 480 72 30 –6 –60

4.5



Figure 4.3 Ratio Correction Factor vs. Calibration Point

Figure 4.4 shows the CT Phase Angle Minutes correction vs. the calibration point of the CT example given.

Figure 4.4 Phase Angle Minutes vs. Calibration Point

By equating plots of the instrument correction, you may use plots like these to determine the correction that the SEL-734 applies to the measured parameters.

10

0

0.5

1

1.5

2

2.5

2 3

Calibration Point

Rati

o C

orr

ecti

on

Facto

r

4 5 6

10

0

–200

200

400

600

800

1200

1000

1600

1400

1800

2 3

Calibration Point

Ph

ase

An

gle

Min

ute

s

4 5 6

4.6


MeteringInstantaneous Metering

Instantaneous MeteringUse instantaneous metering to monitor power system parameters in real time. The SEL-734 provides these readings:

➤ Fundamental phase voltages and currents

➤ RMS phase voltages and currents

➤ Phase-to-phase voltages

➤ Sequence voltages and currents

➤ Real, 4-quadrant reactive, and apparent power

➤ Distortion power

You can use the MET command (see MET Commands on page 10.19) to display these instantaneous values or you can view them from the front panel.

Table 4.2 Metering Quantity Definitions (Sheet 1 of 2)

Term Definition

Real Power (P) Power that produces actual work, measured in watts; the portion of apparent power that is real, not imaginary.

Real Power Average (PAVE) Real power (P) averaged over a one-second interval.

Real Power Three Phase (P3P) Three-phase real power measured in watts.

Reactive Power (Q) Reactive power measured in volt-amps reactive (VAR). The product of the voltage and current multiplied by the sine of the angle between the two.

Reactive Power Average (QAVE) Reactive power (Q) average over a one-second interval. QAVE is forced to zero when the apparent power (S) is less than or equal to real power (P) • 1.001.

Reactive Power Three-Phase (Q3P) Three-phase instantaneous reactive power measured in volt-amps reactive (VAR).

Apparent Power (S) Complex power expressed in units of volt-amps (VA). Accounts for both real (P) and reactive (Q) power dissipated in a circuit: S = P + jQ. This is power at the fundamental frequency only; no harmonics are included in this quantity.

Total Harmonic Distortion (THD) The ratio of the sum of the power of all harmonic frequencies above the fundamental fre-quency to the power of the fundamental frequency. Usually expressed as a percentage, large numbers indicate increased distortion.

Group Total Harmonic Distortion (THDG)

The ratio of the sum of the power of all harmonic frequencies including interharmonics above the fundamental frequency to the power of the fundamental frequency. Usually expressed as a percentage, large numbers indicate increased distortion.

K-factor A measure of the effect of harmonic load currents used for derating equipment (transformers), as described in ANSI/IEEE C57.110. The larger the K-factor the greater the harmonic heating effects. A K-factor of 1.0 indicates a linear load (no harmonics). K-factor is the summation of the square of a particular harmonic current multiplied by the square of the harmonic number. K-factor transformers have additional thermal capacity, design features that minimize harmonic current losses, and oversized thermal connections.

Vector Power (U) Apparent power with the addition of distortion power representing the third dimension (k) in the power triangle.

Measured in volt-amps (VA), U equals iP + jQ + kD, where kD is distortion power that is the result of harmonics and noise.

4.7


MeteringDemand Metering

Demand MeteringYou can choose between three types of demand metering with the enable setting:

➤ EDEM = THM (Thermal Demand Meter)

➤ EDEM = ROL (Rolling Demand Meter)

➤ EDEM = BLOK (Block Demand Meter)

The demand metering settings in Table 4.8 are available via the SET command (see Table 9.1 and SEL-734 Settings Sheets in Section 9: Settings). Also refer to MET D (Demand Metering) on page 10.19).

The SEL-734 provides demand and peak demand metering for the values listed in Table 4.3. The values contain harmonics sampled at 8 kHz.

Distortion Power Ratio (Dx) Distortion power is calculated as the ratio of average power to fundamental power and is reported in a percentage. It is calculated on a per-phase or three-phase basis as follows:

where:

Dx is the distortion power ratio for the respective phase

Px_avg is the average power for the respective phase

Px is the fundamental power for the respective phase

(x represents A, B, C, or 3P values)

I or V MAG Current and voltage magnitudes updated every 25 ms with fundamental data.

I or V ANG Current and voltage angles updated every 25 ms.

I or V RMS or AVG Current and voltage magnitudes updated every 1 s with 8 kHz data.

P, Q, or S Power magnitudes updated every 1 s with fundamental data.

P_AVE, Q_AVE, or S_AVE Power magnitudes updated every 1 s with 8 kHz data.

Power Factor (PF) Displacement power factor calculated using fundamental voltage and current vectors. Updated every 1 s.

Table 4.2 Metering Quantity Definitions (Sheet 2 of 2)

Term Definition

Dx Px_avgPx

------------------ 1–⎝ ⎠⎛ ⎞ 100=

Table 4.3 Demand and Peak Demand Metering Values

Currents IA,B,C,N Input currents (A primary)

Power MWA,B,C (P) Single-phase megawatts delivered/received

(Form 9 only)

MW3P (P) Three-phase megawatts, Real Power

MVARA,B,C (Q) Single-phase megavars, four-quadrant

(Form 9 only)

MVAR3P (Q) Three-phase megavars, Reactive Power

MVAA, B, C (S) Single-phase apparent power

MVA3P (S) Three-phase apparent power

4.8



Comparison of Thermal, Rolling, and Block Demand Meters

The example in Figure 4.5 shows the response of thermal, rolling, and block demand meters to a 1.0 per unit step energy input.

Figure 4.5 Response of Thermal, Rolling, and Block Demand Meters to a Step Input (Setting DMTC=15 Minutes)

0 5 10 15 Time(Minutes)

1.0

0.5

0Inst

anta

neou

s Cu

rren

t (pe

r uni

t)

StepCurrent

Input


1.00.9

0.5

0Ther

mal

Dem

and

Curr

ent (

per u

nit)

ThermalDemandMeter

Response(EDEM=THM)

DMTC=15 minutes


1.0

0

0.67

0.33

Rolli

ng D

eman

d Cu

rren

t (pe

r uni

t)

RollingDemandMeter

Response(EDEM=ROL)

DMTC=15 minutes


1.0

0

BlockDemandMeter

Response(EDEM=BLOK)

4.9



Thermal Demand Meter Response (EDEM=THM)The thermal demand meter response in Figure 4.5 to the step current input is analogous to the series RC circuit in Figure 4.6.

Figure 4.6 Voltage VS Applied to Series RC Circuit

In the analogy:

➤ Voltage VS in Figure 4.6 corresponds to the step current input in Figure 4.5 (top).

➤ Voltage VC across the capacitor in Figure 4.6 corresponds to the response of the thermal demand meter in Figure 4.5 (middle).

If voltage VS in Figure 4.6 has been at zero (VS = 0.0 per unit) for some time, voltage VC across the capacitor in Figure 4.6 is also at zero (VC = 0.0 per unit).

If voltage VS is suddenly stepped up to some constant value (VS = 1.0 per unit), voltage VC across the capacitor starts to rise toward the 1.0 per unit value. This voltage rise across the capacitor is analogous to the response of the thermal demand meter in Figure 4.5 (middle) to the step current input (top).

In general, because voltage VC across the capacitor in Figure 4.6 cannot change instantaneously, the thermal demand meter response to increasing or decreasing applied instantaneous current is also not immediate. The thermal demand meter response time is based on the demand meter time constant setting DMTC (see Table 4.8). Note in Figure 4.5, the thermal demand meter response (middle) is at 90 percent (0.9 per unit) of full applied value (1.0 per unit) after a time period equal to setting DMTC = 15 minutes, referenced to when the step energy input is first applied.

The SEL-734 updates thermal demand values approximately every second.

Rolling Demand Meter Response (EDEM=ROL)The response of the rolling demand meter in Figure 4.5 to the step current input is calculated with a sliding time-window arithmetic average. The width of the sliding time-window is equal to the demand meter time constant setting DMTC (see Table 4.8). Notice in Figure 4.5, the rolling demand meter response (bottom) is at 100 percent (1.0 per unit) of full applied value (1.0 per unit) after a time period equal to setting DMTC = 15 minutes, referenced to when the step current input is first applied.

The rolling demand meter integrates the applied signal (e.g., step current) input in demand meter subintervals (setting DMSI; see Section 9: Settings). See Table 4.4 for a listing of possible DMTC intervals and DMSI subintervals. The integration is performed approximately every second. The average value for an integrated DMSI-minute subinterval is derived and stored as a

C VcVs

R

+

–

4.10



DMSI-minute total. The rolling demand meter then averages a number of the DMSI-minute totals to produce the rolling demand meter response. In the Figure 4.5 example, the rolling demand meter averages the three latest DMSI-minute totals because setting DMTC = 15 and DMSI = 5 (15/5 = 3). The rolling demand meter response is updated every DMSI (5 minutes), after a new DMSI-minute total is calculated.

The following is a step-by-step calculation of the rolling demand response example in Figure 4.5 (bottom).

Time = 0 MinutesPresume that the instantaneous energy has been at zero for at least 15 minutes before “Time = 0 minutes” (or the demand meters were reset). The three 5-minute intervals in the sliding time-window at “Time = 0 minutes” each integrate to zero.

Rolling demand meter response at “Time = 0 minutes” = 0.0/3 = 0.0 per unit.

Time = 5 MinutesThe three 5-minute intervals in the sliding time-window at Time = 5 minutes each integrate into the 5-minute totals in Table 4.5.

Rolling demand meter response at Time = 5 minutes = 1.0/3 = 0.33 per unit.


Table 4.4 Demand Meter Settings and Settings Ranges

Interval Length (DMTC Minutes)

DMSI 1 5 10 15 30 60

Subin

terv

al L

ength

(min

ute

s)

1 5 10 15 30 60

1 5 5 15 30

2 3 10 20

1 6 15

5 12

3 10

6

5

Table 4.5 Time = 5 Minutes Intervals

5-Minute Totals Corresponding 5-Minute Interval

0.0 per unit –10 to –5 minutes

0.0 per unit –5 to 0 minutes

1.0 per unit 0 to 5 minutes

1.0 per unit total

4.11






Block Demand Meter Response (EDEM=BLOK)The block demand meter calculations are similar to rolling demand except where the block demand meter integrates the applied signal (e.g., step current) input over the entire DMTC setting instead of DMSI-minute subintervals.

End of Interval Pulse (EOIP)The end of each demand interval is represented by the Meter Word bit EOIP. The EOIP Meter Word bit is pulsed for a given time adjusted by the EOIPT (End of Interval Pulse Timer) setting. The EOIPT setting has a range of 1–5 seconds, or OFF. If rolling demand (ROL) is enabled, the EOIP Meter Word bit asserts at the end of every subinterval.

Predictive Demand Meter Response (EPRED=Y and EDEM=ROL or BLOK)The SEL-734 supports the processing of predictive demand of any peak demand value. Predictive demand is calculated and updated every second. The predictive demand calculation is shown in Equation 4.1.

Equation 4.1



0.0 per unit –5 to 0 minutes



2.0 per unit total






3.0 per unit total

where:Avg = Average of 1-second averages taken already in the

demand intervalTElapsed = Seconds elapsed in the current demand intervalPresent = Most recent 1-second average value

TRemaining = Seconds remaining in demand intervalDMTC = Demand Metering time constant

PredDemand = Avg TElapsed ondssec( ) Present TRemaining ondssec( )• +•

DMTC 60• ----------------------------------------------------------------------------------------------------------------------------------------------

4.12



If any of the predictive demand settings are changed, predictive demand is reset.

If the calculation value is above the PREDAL (predictive demand alarm threshold) setting, the meter asserts the PREDAL Meter Word. When the value drops below the PREDAL level, the meter deasserts the PREDAL Meter Word. Figure 4.7 shows the logic used for the PREDAL alarm.

The SEL-734 requires three one-second calculations to be above the PREDAL threshold or below the threshold in order to assert or deassert the PREDAL Meter Word bit. This requirement minimizes the number of nuisance alarms from starting of large loads.

Figure 4.7 PREDAL Logic

Demand Meter Settings

Execution: every second

Set

Output

executions

ResetPREDALD(PREDAL Setting –1) = dropout threshold

(PREDAL Setting) = pickup thresholdPREDALP

MeterWord

BitPREDAL

Group SettingsPREDk = value

executions

Enables

EPRED=Y

enablecalculation

EDEM=BLOK

EDEM=ROL

Group SettingsEPRED = Y

3.00

0.00

3.00

0.00

Table 4.8 Demand Meter Settings and Settings Range

Setting Definition Range

EDEM Demand meter type THM = thermalBLOK = blockROL = rolling

DMTC Demand meter time constant 1, 5, 10, 15, 30, or 60 minutes

DMSI Demand meter sub-interval See Table 4.4

PDEMP Phase demand current pickup OFF, 0.10–3.20 Amps, secondary

NDEMP Neutral ground demand current pickup

OFF, 0.10–3.20 Amps, secondary

GDEMP Residual ground demand current pickup


QDEMP Negative-sequence demand current pickup


DBLOCK Demand block time OFF, 1–300 minutes

EOIPT End of interval pulse timer OFF, 1–5 seconds

EPRED Predictive demand Y, N(hidden if EDEM ≠ ROL or BLOK)

PRED Predicted Peak demand quantity Any marked demand metering quantity from Table H.2 on page H.4 (hidden if EPRED = N)

PREDAL Peak demand alarm level 0–999999.99 (Primary Units hidden if EPRED = N)

4.13



The following examples in this section illustrate demand current.

The demand current pickup settings in Table 4.8 are applied to demand current meter outputs as shown in Figure 4.8. For example, when residual ground demand current IG(DEM) goes above corresponding demand pickup GDEMP, Meter Word bit GDEM asserts to logical 1. Use demand current logic outputs PDEM, NDEM, GDEM, and QDEM to alarm for high loading conditions or unbalance conditions.

Figure 4.8 Demand Current Logic Outputs

NOTE: Changing setting EDEM, DMTC, or DMSI resets the present internal demand meter values to zero. Demand current pickup settings PDEMP, NDEMP, GDEMP, and QDEMP can be changed without affecting the demand meters.

Demand CurrentPickup Settings(A secondary)

Serial PortCommand

MET RD

QDEMPQDEM

GDEMPGDEMIG(DEM)

IN(DEM)

3I2(DEM)

IC(DEM)

IB(DEM)

IA(DEM)

NDEMPNDEM

PDEM

DemandCurrents

PDEMP

max.phase

demand

(residual)

resetdemand

resetdemand

resetdemand

resetdemand

IA

IN

IG

3I2

MeterWordBits

Demand Function

Thermal (EDEM = THM)or

Rolling (EDEM = ROL)or

Block (EDEM = BLOK)

Demand Function



Block (EDEM = BLOK)

Demand Function



Block (EDEM = BLOK)

Demand Function



Block (EDEM = BLOK)

InstantaneousCurrents

4.14



View or Reset Demand Metering Information

Via Serial PortSee MET D (Demand Metering) on page 10.19. Use the MET D command to display present demand and peak demand metering for the following values:

The MET R D command resets the demand metering values. The MET R P command resets the peak demand metering values. The MET D P command displays peak demand metering at the last MET R P command. The MET D T command displays the values and times at which the peak demands were set.

If using rolling demand, after resetting the demand values, there may be a delay of up to two times the DMTC setting before the demand values are updated.

Via Front PanelThe information and reset functions available via the previously discussed serial port commands MET D, MET R D, MET R P, and MET D P are also available via the front-panel pushbuttons. See Figure 11.3.

Via Remote Bits and DNPThree settings allow configuration of remote bits to reset demand, peak demand, or energy values in the SEL-734. Add a remote bit, RB01–RB16, to the global settings RSTDEM, RSTPKDM, or RSTENGY to remotely reset each value. A DNP master can now write a binary output corresponding to a remote bit to reset values in the SEL-734. Optionally, add a remote analog quantity, RA00–RA31, as a password.

For example set RSTPKDM := RB01 AND RA00=12345. Now, to reset the peak demand value in the SEL-734, the DNP master writes a value of 12345 to RA00 and asserts RB01 to force the SEL-734 to reset the peak demand value. After resetting the value, the master should write a new value to RA00 to clear the password.

Demand Metering Updating and Storage

The SEL-734 updates demand values approximately every second.

The meter stores peak demand values to nonvolatile memory once every minute (it overwrites the previous stored value if it is exceeded). Should the meter lose control power, it will restore the peak demand values saved by the meter during the last save to nonvolatile memory.

Table 4.9 Present and Peak Demand Values


Power MWA,B,C (P) Single-phase megawatts delivered/received

(Form 9 only)

MW3P (P) Three-phase megawatts delivered/received

MVARA,B,C (Q) Four-quadrant single-phase megavars

(Form 9 only)

MVAR3P (Q) Four-quadrant three-phase megavars

MVAA,B,C (S) Single-phase megavoltamps delivered/received

(Form 9 only)

MVA3P (S) Three-phase megavoltamps delivered/received

4.15


MeteringEnergy Metering

To avoid influencing the demand metering peak recording for a system fault, peak recording is momentarily suspended when Meter Word bit FAULT is asserted (= logical 1). See the explanation for the FAULT setting in Maximum/Minimum Metering on page 4.19.

Energy MeteringView or Reset Energy Metering Information

Via Serial PortUse the MET E command to display accumulated single- and three-phase megawatt-, megavoltamp-, four-quadrant megavar-hours, volt-hours, and amp-hours. The MET R E command resets the accumulated single- and three-phase megawatt-, megavoltamp-, megavar-hours, volt-hours, and amp-hours. Level 2AC access is required to reset energy metering values.

Via Front PanelThe information and reset functions available via the previously discussed serial port commands MET E and MET R E are also available via the front-panel pushbuttons. See Figure 11.3.

Via Remote Bits and DNPSee Via Remote Bits and DNP on page 4.14.

Energy Metering Updating and Storage

The SEL-734 updates energy values every second.

The meter saves energy values to nonvolatile memory once every minute (it overwrites the previous stored value if it is exceeded). Should the meter lose control power, it will restore the energy values saved by the meter during the last save to nonvolatile memory. See Rollover on page 9.15 for the number of digits displayed and rollover.

Energy Cut-Off Point As the power factor approaches zero, small phase angle measurement errors result in relatively large errors in real power (watts) measurements. This is because of the sensitivity of the cosine function as the phase angle approaches 90° (PF = 0).

To prevent erroneous real power measurements under near PF = 0 conditions, the SEL-734 supports an energy cut-off angle using the ANGCUT (see SET G Command on page SET.6) setting. When the phase angle between the current and voltage reaches the cut-off setting, rms watts are zeroed. The ANGCUT setting supports cut-off angles from 1° to 10°.

Figure 4.9 demonstrates that when the vectors VA and IA have a relative phase angle difference of 0°, only real power (watts) flows through a power system. For example, 120 V • 5 A • Cos(0°) = 600 W.

Figure 4.9 Power Factor = 1

NOTE: Single-phase quantities are available only in Form 9 models.

IA

VA

4.16


MeteringEnergy Interface

Figure 4.10 demonstrates that when the vectors VA and IA have a relative phase angle difference of 90°, only reactive power (VARs) flows through a power system. For example, 120 V • 5 A • Cos(90°) = 0 W = 600 VARS.

Figure 4.10 Power Factor = 0

In a real power system, and during accuracy testing, the phase angles of the current and voltage will fluctuate slightly. As the IA phase angle fluctuates, the relative VAR measurement will not change much, but the relative watt measurement will change noticeably. In addition, some of the watts will report as Delivered and some of the watts will report as Received. The ANGCUT setting will prevent the SEL-734 from recording these small watt values when the power factor is close to 0 and will prevent VARs from recording when the power factor is close to 1.

Figure 4.11 Power Factor = ±0.02

Reactive power (VAR) measurements are suppressed in a similar manner. See Table 4.10.

Preloading Energy Values

You can preload the energy values in the meter using the SET E command from 0 to 99,999,999,999. Amp-hour and Volt-hour quantities are set in UNITY units; all other energy values are set in KILO units. Use this command to preload energy values when replacing a meter for maintenance or upgrade.

Energy InterfaceIntroduction The SEL-734 represents metering values differently through the interface of

each protocol. The list below details how each interface reports energy data and illustrates how the SEL-734 displays watt-hours.

Table 4.10 Example ANGCUT Setting

ANGCUT Setting Watts Zeroed Between VARs Zeroed Between

OFF n/a n/a

2 88° to 92° and –88° to –92° 2° to –2° and 178° to –178°

10 80° to 100° and –80° to –100° 10° to –10° and 170° to –170°

IA

VA

IA

VA

4.17



Overview The Energy Interface Table (Table 4.11) outlines the effect of various SEL-734 settings on each energy interface.

Interfaces

Front-Panel LCD (HMI) The front-panel LCD reports display energy values in scaled primary units affected by the FP_SCALE, FP_DND, and FP_DECPL settings.

ACSELERATOR QuickSet Energy ReportThe ACSELERATOR QuickSet Energy report displays energy values in scaled primary units affected by the SCALE, DND, and DECPL settings.

ACSELERATOR QuickSet LDP ReportThe ACSELERATOR QuickSet LDP report displays energy values in secondary units with no scaling. The LDP report includes the CTR and PTR values allowing post-read calculation of primary units.

Energy PreloadThe ACSELERATOR QuickSet Energy Preload settings accept settings in primary Kilo units and with a maximum input of 99,999,999,999.

ModbusEnergy Registers

The SEL-734 reports Modbus energy records 0400–045F in secondary units as LONG100s scaled by100 with unity scaling and rollover at 9,999,999.99.

Table 4.11 Energy Interface Table

Interface ScalingNumber of digits

Number of decimal places

MEGA KILO UNITY Pri Sec RolloverMax digits (including

decimal places)

Front-Panel LCD

FP_SCALE FP_DND FP_DECPL X X X X X 11

ACSELERATOR QuickSet Energy

SCALE DND DECPL X X X X X 8

ACSELERATOR QuickSet LDP

2 X X X 9

Modbus Energy x100 2 X X X 9

Modbus LDP x100 2 X X X 9

Modbus Front Panel

FP_SCALE FP_DND FP_DECPL X X X X X 9

DNP Counters DECPLE OR PER POINT

X X X 216 or 232 depend-ing on variation

DNP LDP Counters

x100 2 X X X 9

Fast Meter FLOAT 32 X X 6

Fast Message 0 X X X 9

4.18



Load Profile RegistersThe SEL-734 reports Modbus LDP records 2000–2FFF in secondary units as LONG100s scaled by 100 and rollover at 9,999,999.99.

Front-Panel Energy RegistersThe SEL-734 reports Modbus front-panel energy records 0480–04DF in primary as LONGs affected by the FP_DND, FP_DECPL, and DP_SCALE settings. Energies displayed as LONGs rollover at 999,999,999 and do not include decimal places.

DNPCounters

The SEL-734 reports DNP counters (Object 20, Index 00–38) in primary units affected by the DECPLE setting and per-point scaling. Optimized for reporting energy data, binary counters rollover at 216 for Variation 6 or 232 for Variation 5 values.

Load Profile CountersThe SEL-734 reports DNP Load Profile counters (Object 20, Index 40–1008) in secondary units scaled by 100. Load Profile counter information rolls over at 9,999,999.99. SEL recommends using 32-bit counter information because the 16-bit load profile counter information does not rollover in a predictable manor.

Analog InputsSEL recommends Analog Inputs (Object 30) for all analog data except for energy because the Analog Input data saturates at their binary full-scale values of 216 or 232 and do not rollover.

Time-of-Use (TOU)ACSELERATOR QuickSet HMI

The ACSELERATOR QuickSet TOU HMI report displays Time-of-Use data in primary Mega units that do not rollover.

MODBUS TOU RegistersThe SEL-734 reports Modbus TOU energy data in primary units scaled by the SCALE and DND settings.

Front-Panel LCD (HMI)The front-panel LCD displays Time-of-Use energy in primary units scaled by the FP_SCALE, FP_DND, and FP_DECPL settings.

Fast Meter (A5D1)The SEL-734 reports Fast Meter Messages energy data as FLOAT32 values for each phase. Fast Meter data is in primary Mega units, does not rollover, and is not affected by scaling settings.

Fast Message (A546 Function Code 1-Data Read Request)The SEL-734 reports Fast Messages in Kilo units that rollover at 999,999,999.

4.19


MeteringMaximum/Minimum Metering

Maximum/Minimum MeteringView or Reset Maximum/Minimum Metering Information

Via Serial PortUse the MET M command to display maximum/minimum metering and the date and time associated for the following values:

The MET R M command resets the maximum/minimum metering values.

The power maximum and minimum values can be negative or positive, indicating the range of power flow that has occurred since the last MET R M reset command. These functions simulate analog meter drag-hands, with the maximum value representing the upper drag-hand and the minimum value representing the lower drag-hand.

Via Front PanelThe metering and reset functions available via serial port commands MET M and MET R M are also available via the front-panel pushbuttons. See Figure 11.3.

Maximum/Minimum Metering Update and StorageThe maximum/minimum metering function is intended to reflect normal load variations rather than fault conditions or outages. Therefore, maximum/ minimum values are updated only if the following conditions are met:

➤ DFAULT is deasserted (= logical 0).

➤ For Form 9 voltage values VA,B,C or Form 5 voltage values VAB,BC,CA, the voltage is above the corresponding 25.0 V secondary threshold.

➤ For current values IA,B,C,N the current is above the corresponding 0.05 A secondary threshold.

➤ For power values MW3P and MVAR3P, all three phase currents IA,B,C are above threshold and all three voltages VA,B,C (or VAB,BC,CA) are above threshold.

➤ The metering value is above the previous maximum or below the previous minimum for approximately four seconds.

The meter saves maximum/minimum values to nonvolatile memory once every minute (it overwrites the previous stored value if it is exceeded). Should the meter lose control power, it will restore the maximum/minimum values saved by the meter during the last save to nonvolatile memory.


Voltages VA,B,C Input voltages (kV primary, Form 9 only)

VAB,BC,CA Input voltages (kV primary, Form 5 only)

Power MW3P (P) Three-phase megawatts (primary)

MVAR3P (Q) Three-phase megavars (primary)

NOTE: The values used by the maximum/minimum metering are the same values used by the regular MET command (serial port or front panel), which are one-second averaged values. The maximum/minimum metering function updates every second. These values are relatively immune to transient conditions.

4.20


MeteringMaximum/Minimum Metering

Maximum/Minimum Metering Elements

The SEL-734 will not meter certain values during faults to ensure that only billable quantities are recorded. When asserted, the overcurrent elements ensure that peak demand, maximum metering, energy, and crest factors are not recorded. Undervoltage elements will not suspend any meter recording, but can be used with any SELOGIC control equation.

Overcurrent ElementsThe SEL-734 asserts Meter Word bits when it detects an overcurrent fault. It detects steady-state overcurrent faults or a rapidly changing current condition. Figure 4.12 shows the logic processing of the fault elements.

Figure 4.12 FAULT and DFAULT Meter Word Bit Logic

The current pickup thresholds vary based on the Current Class option of the meter. Figure 4.12 shows the Fault Current Threshold and Fault di/dt Threshold inputs to the logic. Table 4.12 below defines these thresholds.

FAULT: Meter Word bit that asserts if the positive-sequence current exceeds the Fault Current Threshold or the metered current rises faster than the Fault di/dt Threshold between any two power system cycles. Peak demand, maximum/minimum metering, energy, and crest factor metering are suspended when the FAULT Meter Word bit is asserted (logical 1).

DFAULT, Delayed Fault: Meter Word bit that asserts identically to the FAULT bit and suspends the same metering values. The DFAULT Meter Word bit remains asserted for 60 seconds after the fault condition has been removed.

FLTBLK, Fault Bit Block SELOGIC Control Equation: SELOGIC control equation setting FLTBLK (Fault block) has to be deasserted (logical 0) for the FAULT Meter Word bit to assert during a fault on the system. Configure FLTBLK to override, when asserted, the FAULT Meter Word bit. The default setting for FLTBLK is deasserted.

Table 4.12 FAULT Thresholds

Current Class OptionFault Current

ThresholdFault di/dt Threshold

CL2 6.3 3

10 V LEA 12 10

CL10/CL20, 150 V LEA, 25 V LEA 21 10

060sec

FAULT

DFAULT

Fault di/dtThreshold

MeterWordBits

FaultCurrent

Threshold

I1k

I1(k-16)

|I1k| - |I1(k-16)|

SELOGIC Control Equation: FLTBLK

NOTE: Meter Word bit FAULT and DFAULT also control other Meter functions.

4.21


MeteringCrest Factor Metering

Undervoltage Elements27n (n = A, B, or C), Undervoltage Elements: Meter Word bits that assert for each phase when the voltage drops below the threshold defined by the 27P1P and VBASE settings. Form 9 meters assert the undervoltage elements based on phase-to-neutral voltage. Form 5 meters assert the undervoltage elements based on phase-to-phase voltages.

27P1P, Undervoltage Pickup Percent of VBASE: Undervoltage pickup threshold measured as percent of the VBASE setting. If any voltage drops below the 27P1P setting, the undervoltage element asserts.

Crest Factor MeteringAlong with total harmonic distortion, crest factor is an indication of power quality. A sinusoidal waveform crest factor is 1.414 and a square wave crest factor is 1.0. The SEL-734 records the maximum and minimum crest factor metering values.

The SEL-734 uses the equation shown in Equation 4.2 to calculate crest factor values every second.

Equation 4.2

View or Reset Crest Factor Metering Information

Via Serial PortSee MET CF (Crest Factor Metering) on page 10.19. Use the MET CF command to display crest factor metering for the following values:

Use the MET R CF command to reset the crest factor metering values.

Via Front PanelThe metering and reset functions available via serial port commands MET CF and MET R CF are also available via the front-panel pushbuttons. See Figure 11.3.

Crest Factor Metering Update and Storage

The crest factor metering function is intended to reflect normal load variations rather than fault conditions or outages. Therefore, crest factor values are only updated if the following conditions are met:

➤ DFAULT is deasserted (= logical 0).

➤ For Form 9 voltage values VA,B,C or Form 5 voltage values VAB,BC,CA, the voltage is above the corresponding 25.0 V secondary threshold.

➤ For current values IA,B,C,N, the current is above the corresponding 0.05 A secondary threshold.

The SEL-734 stores crest factor values the same as maximum/minimum values.

Crest Factor Peak ValueRMS Value----------------------------=


Voltages VA,B,C Input voltages (kV primary, Form 9 voltage only)

VAB,BC,CA Input voltages (kV primary, Form 5 voltage only)

Reset Time Last time the maximum/minimum meter was reset

NOTE: Meter Word bit FAULT and DFAULT also control other Meter functions.

4.22


MeteringHarmonic Metering

Harmonic MeteringThe SEL-734 provides harmonic measurements for the following values:

➤ Harmonic magnitudes for voltage, current, and power

➤ Harmonic angles for voltage and current

➤ Percent of fundamental harmonic magnitudes for voltage and current

The 0734P model provides harmonic measurements up to the 50th order. The 07340 model provides harmonic measurements up to the 15th order. Both models provide SELOGIC harmonic threshold alarms for the 2nd through the 15th harmonic order.

Harmonic Percentage Harmonics from the second to fifteenth are converted into a percentage of the fundamental and compared to the threshold (HARM02 to HARM15). The HARMTRIG setting determines whether HARM02-HARM15 are triggered on voltage and/or current harmonics. Set HARMTRIG to ALL to trigger on both voltage and current, to VOLTAGE to trigger on voltage only, or to CURRENT to trigger on current only harmonics. If the threshold is enabled and the harmonic is above the set threshold, then the respective harmonic Meter Word bit (HARM02 to HARM15) asserts. The bit will deassert when the respective harmonic falls below the set threshold. Harmonics for currents and voltages are calculated on a per-phase basis; any single-phase harmonic value asserts the HARM02–HARM15 Meter Word bits. If any harmonic Meter Word bit is set, then the FALARM (frequency alarm) Meter Word bit is set.

If the given harmonic threshold is exceeded, the meter Meter Word bit will assert (logical 1).

EXAMPLE 4.1 Harmonic Alarm Example

Suppose that you had noticed that approximately once a month the system experienced a power failure. The cause was believed to be the starting of some large loads that induced harmonics into the system, but this was not verified. With the SEL-734, you made the following settings:

SET HARM02 = 10HARM03 = 10

•••

HARM07 = 10SET L OUT101 = HARM02 OR HARM03 OR HARM04 OR HARM05 OR HARM06 OR HARM07SET R SER1 = HARM02, HARM03, HARM04, HARM05, HARM06, HARM07

You then monitored OUT101 via the SCADA system and noticed that every time a certain load was started, the 3rd harmonic was generated in significant levels.

Harmonic Magnitudes The SEL-734 calculates and updates harmonics as absolute magnitudes once every four seconds. The MET H M command displays the Harmonic Magnitude report. Reported currents and voltages range from 0.00–22.00 amps secondary and 0.00–300.00 volts secondary, respectively. Form 9 and Form 5 reports are identical, except that all entries in the IB columns are filled with zeroes. Set INCIHQ to Y (YES) to include interharmonic values in the harmonic calculations.

4.23



Interharmonic Magnitudes

The SEL-734 calculates interharmonic magnitudes (in accordance with IEC 61000-4-7) from 20 Hz to 3285 Hz in 5 Hz bins. ACSELERATOR QuickSet HMI displays individual interharmonic magnitudes with text and graphical views.

The SEL-734 meter can report integer harmonics, or integer harmonics combined with interharmonics. If the INCIHQ Include Interharmonics Quantities setting is Y, harmonic magnitudes include all frequencies in a 50 Hz or 60 Hz window centered on the integer harmonic frequency. For example, in a 60 Hz system, the meter will report the third harmonic (180 Hz) inclusive of frequencies from 150 Hz to 210 Hz. Figure 4.13 exemplifies a harmonic report with and without interharmonic frequencies with the INCIHQ setting equal to Y and N.

Figure 4.13 Interharmonics vs. Integer-Harmonics Example at the Third Harmonic

Use the MET H A command to display all harmonic and interharmonic magnitudes in 5 Hz bins.

Each Magnitude value has an associated analog quantity (see Appendix H: Analog Quantities) that uses the following format:

HRMxx_yyM

These analog values are available for use in SELOGIC control equations.

where:xx = the harmonic number (2–50 or 2–15)yy = the specific current or voltage phase (IA, IB, IC, IN, VA, VB, or VC)

4.24



K-Factor Calculation Another use for harmonic metering is to prevent transformer overheating due to the harmonics. The meter calculates K-factor on a per-phase and three-phase basis for use in the detection and monitoring of the harmonics. The K-factor is calculated for each phase current channel by the following equation.

Equation 4.3

Distortion Power Distortion power is calculated as the ratio of average power to fundamental power and is reported in a percentage. It is calculated on a per-phase or three-phase basis as follows.

Equation 4.4

Total Harmonic Distortion (THD)

Total Harmonic Distortion (THD) per phase is calculated as follows.

Equation 4.5

where:x = the channel (A, B, C)h = the harmonic number (1 to 25)

KFACTOR_x

Ixh2 h

2

h=1

25∑

I21∑

---------------------=

where:Dx = the distortion power ratio for the respective phase

Px_avg = the average power for the respective phasePx = the fundamental power for the respective phase

Dx Px_avgPx

------------------ 1–⎝ ⎠⎛ ⎞ 100=

where:X = the appropriate channel IA, IB, IC, VA, VB, VC, etc.ht = the total number of harmonics (15 or 50, based on part

numberHXn = the harmonic value of the respective harmonicHX1 = the harmonic value of the fundamental frequency

n = the harmonic number

THDX

ht

n=2∑ HX

2n

HX1-------------------------------

⎝ ⎠⎜ ⎟⎜ ⎟⎜ ⎟⎛ ⎞

100=

4.25


MeteringTransformer/Line Loss Compensation

Group Total Harmonic Distortion (THDG)

Group Total Harmonic Distortion (THDG) per phase is calculated as follows. Refer to IEC 61000-4-7:2002–2008 for harmonic group calculations.

. Equation 4.6

Transformer/Line Loss CompensationEstimate power transmission losses given known system parameters with transformer/line-loss compensation. Calculations to implement loss compensation in the SEL-734 are not required. Inputs to the meter use given nameplate transformer specifications and line resistance. The meter adds or subtracts the loss compensation based on these inputs.

Power is delivered from the power supplier to the point of consumption over a network of transmission lines and through transformers. In addition to generating power for customer loads, the power supplier must supply power to overcome transmission system losses. To increase billing precision, the SEL-734 can compensate for these resistive and inductive power transmission losses. Without loss compensation, power suppliers are unable to bill customers for losses that occur before the metering point.

In a system, there are four possible scenarios for the billing point as compared to the meter position. Figure 4.14 and Table 4.13 show the addition and subtraction of line and transformer loss compensation. Use the billing position (BPOS) and meter position (MPOS) settings to replicate actual system conditions.

Figure 4.14 Meter and Billing Positions

where:X = the appropriate channel IA, IB, IC, VA, VB, VC, etc.ht = the total number of harmonics (15 or 50, based on part

numberHXgn = the harmonic group value of the respective harmonica

a Refer to IEC 61000-4-7:2002—2008 for THDG calculations.

HXg1 = the harmonic group value of the fundamental frequency

n = the harmonic number

THDGX

ht

n=2∑ HXgn

2

HXgl----------------------------------

⎝ ⎠⎜ ⎟⎜ ⎟⎜ ⎟⎛ ⎞

100=

Transformer

Load LineSupply Line

BP1 BP3BP2 BP4LoadPower

Supplier

4.26



View and Set Transformer/Line Loss Compensation

Use the MET L and SET commands to view and set the transformer/line losses calculated by the meter (see MET L (Transformer/Line Loss Metering) on page 10.21). Values shown in the MET report are uncompensated. Calculations are performed every second to compensate the average power, demand, peak demand, and energy values, as shown in Table 4.14.

Table 4.13 Meter Power Calculation Corrections According to Meter Position

BPOS MPOS Change to Calculated Power

BP1 BP1 No adjustment

BP2 Supply line losses subtracted

BP3 Supply line and transformer losses subtracted

BP4 Transformer, supply line, and load line losses subtracted

BP1 BP2 Supply line losses added

BP2 No adjustment

BP3 Transformer losses subtracted

BP4 Transformer and load line losses subtracted

BP1 BP3 Transformer losses and supply line losses added

BP2 Transformer losses added

BP3 No adjustment

BP4 Load side line losses subtracted

BP1 BP4 Transformer, supply line, and load line losses added

BP2 Load line and transformer losses added

BP3 Load line losses added

BP4 No adjustment

Table 4.14 Analog Values Affected by Transformer/Line Loss Compensation (Sheet 1 of 2)

Demand

MWADI MVRADI_LG MVRADO_LG

MWBDI MVRBDI_LG MVRBDO_LG

MWCDI MVRCDI_LG MVRCDO_LG

MW3DI MVR3DI_LG MVR3DO_LG

MWADO MVRADI_LD MVRADO_LD

MWBDO MVRBDI_LD MVRBDO_LD

MWCDO MVRCDI_LD MVRCDO_LD

MW3DO MVR3DI_LD MVR3DO_LD

Peak Demand

MWAPI MVRAPI MVRAPI_LG MVRAPO_LG

MWBPI MVRBPI MVRBPI_LG MVRBPO_LG

MWCPI MVRCPI MVRCPI_LG MVRCPO_LG

MW3PI MVR3PI MVR3PI_LG MVR3PO_LG

MWAPO MVRAPO MVRAPI_LD MVRAPO_LD

MWBPO MVRBPO MVRBPI_LD MVRBPO_LD

MWCPO MVRCPO MVRCPI_LD MVRCPO_LD

MW3PO MVR3PO MVR3PI_LD MVR3PO_LD

4.27



Transformer/Line Losses Compensation (ETLLC) must be enabled to compensate for losses or to program loss compensation settings. Copper (load) and iron (no load) transformer loss compensation can be calculated independently by enabling the ELCU and ELFE settings.

The SEL-734 requires the user input shown in Table 4.15 to calculate transformer/line loss compensation. All equations that follow in Transformer Losses on page 4.28 and Line Losses on page 4.29, show how the meter performs loss calculations and are not required of the user.

Energy Metering

MWHAI MVRHAI_LG MVRHAO_LG

MWHBI MVRHBI_LG MVRHBO_LG

MWHCI MVRHCI_LG MVRHCO_LG

MWH3I MVRH3I_LG MVRH30_LG

MWHAO MVRHAI_LD MVRHAO_LD

MWHBO MVRHBI_LD MVRHBO_LD

MWHCO MVRHCI_LD MVRHCO_LD

MWH3O MVRH3I_LD MVRHCO_LD

MWHA_NET MVRHAI MVRHAO

MWHB_NET MVRHBI MVRHBO

MWHC_NET MVRHCI MVRHCO

MWH3_NET MVRH3I MVRH3O

Time-of-Use Metering

Z_MWH_x_TOT Z_MW_x_PD Z_MW_n_PD Z_MW_x_CD

Z_MVARH_x_TOT Z_MVAR_x_PD Z_MVAR_n_PD Z_MVAR_x_CD

Z_MWH_x_REC Z_MW_x_REC_PD Z_MW_n_REC_PD Z_MW_CD

Z_MVAR_x_REC Z_MVAR_x_REC_PD Z_MVAR_n_REC_PD Z_MVAR_CD

Z_MWH_TOTAL_REC Z_PF_AT_MW_1_PD Z_PF_AT_MW_n_PD Z_MW_MAX_AT_RESET

Z_MVARH_TOTAL_REC Z_PF_AT_MVA_1_PD Z_PF_AT_MVA_n_PD Z_MVAR_MAX_AT_RESET

Z_MWH_AT_RESET Z_PF_AT_MVAR_1_PD Z_PF_AT_MVAR_n_PD Z_MW_AT_MIN_PF_AT_RESET

Z_MWH_SINCE_RESET Z_PF_AT_MW_1_REC_PD Z_PF_AT_MW_n_REC_PD Z_MW_AT_MIN_PF_SINCE_RESET

Z_MVARH_AT_RESET Z_PF_AT_MVA_1_REC_PD Z_PF_AT_MVA_n_REC_PD Z_PF_MIN_AT_RESET

Z_MVARH_SINCE_RESET Z_PF_AT_MVAR_1_REC_PD Z_PF_AT_MVAR_n_REC_PD Z_PF_MIN_SINCE_RESET

Z_PF_AVG_AT_RESET

Z_PF_AVG_SINCE_RESET

Table 4.14 Analog Values Affected by Transformer/Line Loss Compensation (Sheet 2 of 2)

Table 4.15 Required User Input (Sheet 1 of 2)

Setting Description

Transformer Losses

MVA Base transformer 3-phase MVA rating

KVLL Line voltageL-L on primary side of instrument PT in kV

%Z Percent transformer impedance

%IMAG Percent transformer exciting current

LWCU Copper or load-loss in kW

LWFE Iron or no-load-loss in kW

4.28



Transformer Losses Three-phase transformer loss calculations are shown in Equation 4.7–Equation 4.16. For three single-phase transformer applications, %Z, %IMAG, LWCU, and LWFE must be averaged.

Values with subscript “INT” indicate internally calculated values.

Equation 4.7

Equation 4.8

Equation 4.9

Equation 4.10

Where:

Equation 4.11

Equation 4.12

Equation 4.13

Equation 4.14

Equation 4.15

Equation 4.16

LVCU = copper (load) VAR loss, at rated current

LVFE = iron (no-load) VAR loss, at rated voltage

Line Losses

SLR Supply line resistance in ohms primary

SLX Supply line reactance in ohms primary

LLR Load line resistance in ohms primary

LLX Load line reactance in ohms primary

XFTR Power transformer turns ratio

Table 4.15 Required User Input (Sheet 2 of 2)

VSupply

VLoad--------------------

LWCULWCUBINT

I DICFINT• ( )2---------------------------------------=

LWFELWFEBINT

VINT DVCFINT• ( )2-----------------------------------------------------=

LVCULVCUBINT

IINT DICFINT• ( )2------------------------------------------------=

LVFELVFEBINT

VINT DVCFINT• ( )4-----------------------------------------------------=

DICFINT3 KVLL•

MVA 1000• ---------------------------------=

DVCFINT3

KVLL-----------------=

LWCU VACUINT2

LVCUINT2

–=

LWFE VAFEINT2

LVFEINT2

–=

VAFEINT%IMAG

100---------------------- MVA• =

VACUINT%Z100--------- MVA• =

4.29



Line Losses The impedance of power carrying conductors causes line losses. The resistive component causes active power losses (watts) while the reactive component causes reactive power (VAR) losses. If the conductor resistance and reactance are known, the per-phase losses can be calculated. In a three-phase system, the SEL-734 assumes that each conductor has identical impedances and solely series losses are considered.

The SEL-734 uses the following equations to calculate line-loss compensation values.

Supply line loss:

Equation 4.17

Equation 4.18

Equation 4.19

Equation 4.20

Load line losses are calculated similarly by substituting the supply line settings with the load line settings (i.e., replace SPnL with LPnL to calculate the total load-line real power losses).

Example 4.2 shows transformer and line losses as calculated by the SEL-734.

EXAMPLE 4.2 Example Loss Calculations

Figure 4.15 Example System Values

where:SPLL = Total supply line real power lossesSQLL = Total supply line reactive power lossesSPnL = Per-phase supply line real power loss (n = A, B, C)SQnL = Per-phase supply line reactive power losses (n = A, B, C)

SPLSPnLLINT

InINT2

---------------------------=

SLXSQnLLINT

InINT2

----------------------------=

SPLL SPAL SPBL SPCL+ +=

SQLL SQAL SQBL SQCL+ +=

TransformerLoad Line

(11 kV)

1000 A

Supply Line (132 kV)MPOS1 MPOS2 MPOS4MPOS3

LoadPowerSupplier

SEL-734

4.30



Convert transformer rating and losses to per phase:

Equation 4.21

Equation 4.22

Equation 4.23

Equation 4.24

On a per-phase basis:

Equation 4.25

Equation 4.26

Table 4.16 Settings for Example Loss Calculationsa

a See Transformer/Line Losses Settings on page SET.3.

Description Setting Default Setting Value

System Billing Point (1–4) BPOS := 1–4

System Metering Point (1–4) MPOS := 3

Transformer 3-Phase MVA Rating (0.00001–10000 MVA) MVA := 20 MVA

Primary Line-to-Line Voltage (0.00001–10000 kV) KVLL := 11 kV

Transformer Percent Impedance (0.001–19.999%) %Z := 10%

Transformer Percent Exciting Current (0.001–19.999%) %IMAG := 0.1%

Transformer Copper Watt Losses (0.00001–10000 kW) LWCU := 80 kW

Transformer Iron Watt Losses (0.00001–10000 kW) LWFE := 14 kW

Supply Line Resistance (0.0001–999.9999 Ohms) SLR := 1.736 Ω

Supply Line Reactance (0.0001–999.9999 Ohms) SLX := 9.848 Ω

Load Line Resistance (0.0001–999.9999 Ohms) LLR := 1.368 Ω

Load Line Reactance (0.0001–999.9999 Ohms) LLX := 3.759 Ω

Power Transformer Turns Ratio XFTR :=

= 12.0000VSupply

VLoad--------------------⎝ ⎠

⎛ ⎞ 132 kV11 kV

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

MVA1INTMVA

3--------------=

LWCUINTLWCU

3------------------=

LWFEINTLWFE

3-----------------=

IINTMVA

3 KVLL• ------------------------------=

1.05 = 103A•

LVACUINT%Z100--------- MVA1INT• =

0.667 MVA=

LVCUINT VACUINT2

LWCU2

–=

0.666 MVAR=

4.31



Equation 4.27

Equation 4.28

Actual transformer losses for 1000 A load at 11 kV per phase:

Equation 4.29

Equation 4.30

Equation 4.31

Equation 4.32

Equation 4.33

Equation 4.34

Line losses:

Equation 4.35

Equation 4.36

Load line:

Equation 4.37

Equation 4.38

Equation 4.39

LVAFEINT%IMAG

100--------------------- MVA1INT• =

6.667 103– MVA• =

LVFEINT VAFEINT2

LWFE2

–=

4.761 103– MVAR• =

NOTE: The results of Equation 4.31, Equation 4.32, Equation 4.33, and Equation 4.34 are added to averaged power, demand, and energy values when ETLLC is enabled.

Iactual Imetered CTR• 1000 A= =

kVactual Vmetered PTR• 11 kV= =

LWCULoad LWCUINT

Iactual

Ibase---------------⎝ ⎠

⎛ ⎞2

• =

24.2 kW=

LVARCULoad LVCUINT

Iactual

Ibase---------------⎝ ⎠

⎛ ⎞2

• =

604.516 kVAR=

LWFELoad LWFEINT

kVactual

KVLL---------------------⎝ ⎠

⎛ ⎞2

• =

4.667 kW=

LVARFELoad LVAFEINT

kVactual

KVLL---------------------⎝ ⎠

⎛ ⎞4

• =

4.761 kVAR=

XFTR 132 kV11 kV

----------------- 12.0000= =

MPOS 3=

T1 1 if MPOS = 3 or 4=

XFTR otherwise

LLPlosses Iactual T1• ( )2LLR• =

1.736= 103 kW•

LLQlosses Iactual T1• ( )2LLX• =

9.848= 103 kVAR•

4.32


MeteringLoad Profile Report

Supply line:

Equation 4.40

Equation 4.41

Equation 4.42

where:LLP and SLP are line watt losses.LLQ and SLQ are line VAR losses.

Calculating Transformer Test Specifications

The transformer loss inputs of the SEL-734 are designed for user convenience and do not require any calculations. If these inputs are unknown, use percent transformer losses to calculate the required transformer test data. The following equations detail the process of calculating transformer test data.

Equation 4.43

Equation 4.44

Equation 4.45

Equation 4.46

Load Profile ReportThe SEL-734 provides up to 12 independent load profile recorders. MV-90 always reads load profile Recorder 1. Each load profile recorder has its own settings and commands, as shown in Table 4.17:

At the interval given by load profile acquisition rate setting LDAR, the meter adds a record to the load profile buffer. This record contains the time stamp and the present value of the 16 selected analog quantities listed from the load profile list setting LDLIST.

T21

XFTR---------------- if MPOS = 3 or 4=

1 otherwise

SLPlosses Iactual T2• ( )2SLR• =

9.5= kW

SLQlosses Iactual T2• ( )2SLX• =

26.10= kVAR

LWCU%LWCU

100---------------------- MVA•=

LWFE%LWFE

100--------------------- MVA•=

%IMAG

LWFE2

MVA%LVFE

100--------------------⎝ ⎠

⎛ ⎞ 2+

MVA------------------------------------------------------------------------- 100• =

%Z

LWCU2

MVA%LVCU

100---------------------⎝ ⎠

⎛ ⎞ 2+

MVA---------------------------------------------------------------------------- 100• =

Table 4.17 Load Profile Recorder Settings and Commands

Setting/Command First Recorder Second–Twelfth Recorder

Acquisition Rate Setting LDAR LDAR2, LDAR3, ..., LDAR12

Analog Quantity List Setting LDLIST LDLIST2, LDLIST3, ..., LDLIST12

Command LDP LDP2, LDP3, ..., LDP12

4.33



These settings are made and reviewed with the SET R and SHO R serial port commands, respectively.

Change LDFUNCn according to the LDP recorder function you want. The meter logs values according to the LDP recorder function, as described in Table 4.18.

The load profile acquisition rate supports the following values: 3–59 seconds (SEL-734P only) or 1, 5, 10, 15, 30, and 60 minutes.

Refer to Appendix H: Analog Quantities to see a list of labels available in setting LDLIST.

Labels are entered into the LDLIST setting, either comma or space delimited, but are displayed as comma delimited. Load profiling is disabled if the LDLIST setting is empty (i.e., set to NA or 0), which is displayed as LDLIST = 0.

The load buffer is stored in nonvolatile memory and the acquisition is synchronized to the time of day, with a resolution of ±5 seconds. Changing the LDAR setting may result in up to two acquisition intervals before resynchronization occurs. If the LDAR setting is increased, the next acquisition time does not have a complete interval; therefore, no record is saved until the second acquisition time, which is a complete cycle. When the buffer fills up, newer records overwrite older records.

The SEL ACSELERATOR QuickSet software automatically calculates available LDP storage space depending on the meter configuration. Please refer to Table 1.2 for device-specific LDP storage capacity.

The load profile report is retrieved via the LDP command, which has the following format:

LDP [a] [b]

LDP2 [a] [b]

Table 4.18 LDP Functions

LDFUNC Setting Function (Setting, Name)

Function Description

AVG, Average Average quantity during the LDAR period

EOI, End of Interval Instantaneous value at the top of each second, minute, or hour at the rate set by LDAR

COI, Change-Over-Interval Difference in values between the beginning and end of the LDAR period

MAX, Maximum Maximum value during the LDAR period

MIN, Minimum Minimum value during the LDAR period

where:[a] = numeric or date parameter[b] = numeric or date parameter

IMPORTANT: Changes to the LDLIST setting erase all previously recorded Load Profile data.

4.34



The date entries in the above example LDP commands are dependent on the Date Format setting DATE_F.

The load profile output has the following format:

=>>LDP <Enter>

FEEDER 1 Date: 03/03/99 Time: 21:58:06.875STATION A Time Source: int

FID=SEL-734-X109-V0-Z001001-D20030227 CID=760E

# DATE TIME IA IB IC VA VB VC1 *03/03/99 21:55:00 9.99 9.94 9.94 0.10 0.10 0.10

=>>

The SEL-734 places a “*” in the load profile report for any changes in date or time (including Daylight-Saving Time changes), if the meter cycles power, or if TEST mode is entered during the recording interval for easy identification in the report.

If the requested load profile report rows do not exist, the meter responds:

No Load Profile Data

Determining the Size of the Load Profile Buffer

The LDP D and LDP2 D–LDP12 D commands display the maximum number of days of data the meter may acquire with the present settings, before data overwrite will occur for the specified recorder.

=>>LDP D <Enter>There is room for a total of 37 days of data in the load profile buffer, with room for

37 days of data remaining.

=>>

Clearing the Load Profile Buffer

Clear the specified load profile report from nonvolatile memory with the LDP C or LDP2 C–LDP12 C command. Changing the LDLIST setting will also result in the buffer being cleared.

=>LDP C <Enter>

Clear the load profile buffer

Are you sure (Y/N)? Y <Enter>Clearing Complete

Table 4.19 LDP Serial Port Commands

Example LDP Serial Port Command

Response

LDP The SEL-734 returns all LDP data.

LDP 17 The SEL-734 returns the most recent 17 LDP rows.

LDP 10 33 or LDP 33 10 The SEL-734 returns LDP rows 10–33 or 33–10 in chronological or reverse chronological order, respec-tively.

LDP 1/1/2009 The SEL-734 returns all LDP data recorded after 1/1/2009.

LDP 1/1/2009 2/1/2009 or LDP 2/1/2009 1/1/2009

The SEL-734 returns all LDP data recorded between 1/1/2009 and 2/1/2009 in chronological or reverse chronological order, respectively.

4.35



Load Profile Retrieval Using File Transfer

The SEL-734 supports Load Profile data retrieval using the YMODEM file transfer protocol. The ACSELERATOR QuickSet software uses this protocol to rapidly and securely retrieve the SEL-734 LDP data. The YMODEM file transfer LDP data is in secondary units scaled by 100 and rolls over at 999,999,999. The LDP report includes the PTR and CTR values which allow post-read calculation of primary units.

The commands in Table 4.20 describe how to retrieve LDP data over the YMODEM protocol outside of ACSELERATOR Quickset.

The SEL-734 reports binary LDP data in the format show in Table 4.21.

The following definitions describe the LDP data format of the YMODEM response.

Record TypeThe Record Type identifies the type of data present in the data field of the record with a range of 0x0000–0xFFFF. The SEL-734 reports this data in the Big-Endian format with the most significant byte first.

Record SizeThe Record Size is the length, in bytes, of the data field plus 2 bytes for the check sum. The SEL-734 reports this data in the Big-Endian format with the most significant byte first. The smallest record size possible is 0x0002 which

Table 4.20 LDP File Transfer Commands

Command Definition

FILE READ ldp_data.bin Retrieves the LDP settings and configuration data. This does not include the LDP data.

FILE READ ldp2_data.binFILE READ ldp3_data.bin

•

•

•

FILE READ ldp12_data.bin

Retrieves the LDP2–LDP12 settings and configuration data. This does not include the LDP2–LDP12 data. If the SEL-734 does not support LDP2–LDP12 data, it will respond with: File specified does not exist.

FILE READ ldp_data.bin 1/1/00 00:00:00

Retrieves all LDP data, settings, and configuration data.

FILE READ ldp_data.bin MM/DD/YYYY HH:MM:SS MM/DD/YYY HH:MM:SS

Retrieves a specific date range of LDP data which includes settings and configuration data. To read a specific time and date range of LDP data, simply add the start date and end date to the FILE READ command. For example, to retrieve the LDP data for January of 2009, issue the following command: FILE READ ldp_data.bin 01/01/2009 00:00:00 02/01/2008 00:00:00

Table 4.21 LDP Field Format

Offset Name Length (bytes) Binary Equivalent

0 to 1 Record Type 2 16 bit unsigned

2 to 3 Record Size 2 16 bit unsigned

4 to (4 + N – 1) Data Block N (0–65533) 8 bit unsigned

4 + N Record checksum 2 16 bit unsigned

4.36



specifies a data field of 0 bytes in length and a check sum of 2 bytes. The largest record size possible is 0xFFFF, which specifies a data field of 65,533 bytes in length and a check sum of 2 bytes.

Data BlockThe Data Block defines the data payload of the record. The structure of the data is dependent on the record type as defined by the Record Types.

ChecksumThe Checksum is a two byte binary sum of all the bytes stored in the data field of the record. The Checksum allows the master to validate the authenticity of the data stored in a record. The SEL-734 reports this data in the Big-Endian format with the most significant byte first.

Record TypesThe tables below define the data structure and limits of each record type.

Record Type 0064—Meter ConfigurationTable 4.22 Meter Configuration Record (Sheet 1 of 2)

Field Data Structure

Description Min Max Notes

UINT16 Current year

UINT16 Current Julian day

UINT32 Current tenths of millisecond since midnight

UINT8 Time Source 0 = Internal, 1 = External

CHAR[10] Starting daylight-saving config string

CHAR[10] Stopping daylight-saving config string

UINT16 DST forward time (minutes after midnight) 60 1339 0 = disable

UINT16 DST backward time (minutes after midnight) 60 1339 0 = disable

FLOAT32 CTR 1 6000

FLOAT32 CTRN 1 10000

FLOAT32 PTR 1 10000

CHAR[33] FID (firmware version of the meter)

CHAR[22] MID setting of the meter

CHAR[22] TID setting of the meter

UINT8 Meter Form 0 = Form 9, 1 = Form 5

UINT16 Number of SER records available 0 512

UINT16 First LDP record Year

UINT16 First LDP record Julian day

UINT32 First LDP record tenths of milliseconds since midnight

UINT16 Last LDP record Year

UINT16 Last LDP record Julian day

UINT32 Last LDP record tenths of milliseconds since midnight

UINT32 Number of LDP records available or within date range 0 NA

UINT16 LDAR setting 1 3600 Update rate in seconds

4.37



The starting and stopping daylight-saving strings are defined as follows:

UINT16 Number of LDP channels enabled 1 16

CHAR Channel names variesa

a The channel names are in a list, in ASCII, separated with NULL (‘\0’) characters, terminated by 2 NULL (‘\0’) characters in a row.

Table 4.22 Meter Configuration Record (Sheet 2 of 2)


Description Min Max Notes

Nonrepeating (i.e., April 13th 2008)"Nyyyymmdd-" where

yyyy = 4-digit year,mm = 2-digit month,

dd = 2-digit day,“-” (ASCII 0x2d) is the pad

Specific date repeating (i.e., the 1st of every April)"Smmdde----" where

mm = 2-digit month,dd = 2-digit day,

e = weekend behavior, upper 4 bits for Sunday, lower 4 bits for Saturday0 = Allow weekend day1 = Move weekend day forward one day2 = Move weekend day forward two days3 = Move weekend day backward one day4 = Move weekend day backward two days

“-” (ASCII 0x2D) is the pad

Occurrence"xOyw-mm---" (i.e., occurs on the first Sunday of every April) where

x = “I” for inclusive, “-” for noninclusivey = “F” for first, “L” for lastw = day of week (1–7),

mm = 2-digit month“-” (ASCII 0x2D) is the pad

“xOOwomm---” (i.e., occurs on the third Sunday of every April) wherex = “I” for inclusive, “-” for noninclusive,w = day of week (1–7),o = occurrence number (1–5),

mm = 2-digit month“_” (ASCII 0x2D) is the pad

“xOWwomm---” (i.e., occurs on Sunday of the fourth week of April) where

x = “I” for inclusive, “-” for noninclusive,w = day of week (1–7),o = week number (1–6),

mm = 2-digit month“_” (ASCII 0x2D) is the pad

4.38



Table 4.23 describes the load profile records that the SEL-734 reports depending on the values written by the master.

Following (i.e., every Sunday following April 2nd)“xFwmmdd---” where

x = “I” for inclusive, “-” for noninclusive,w = day of week (1–7),

mm = 2-digit monthdd = 2-digit day“_” (ASCII 0x2D) is the pad

Prior (i.e., every Sunday prior to April 15th)“xPwmmdd---” where

x = “I” for inclusive, “-” for noninclusive,w = day of week (1–7),

mm = 2-digit monthdd = 2-digit day“_” (ASCII 0x2D) is the pad

Table 4.23 SEL-734 Load Profile Record Response

Value From Master Response From SEL-734

Start Date/Time

End Date/Time

First LDP Date/Time Last LDP Date/Time Number of Records

None None Date of first record in buffer Date of last record in buffer All

Before None Date of first record in buffer Date of last record in buffer All

Inside None Date of specific record Date of last record in buffer From first specified record to last record in buffer

After None NEVER (zeros) NEVER (zeros) 0

Before Before NEVER (zeros) NEVER (zeros) 0

Before Inside Date of first record in buffer Date of specified record From first record in buffer to last specified record

Before After Date of first record in buffer Date of last record in buffer All

Inside Inside Date of specified record Date of specified record From first specified record to last specified record

Inside After Date of specified record Date of last record in buffer From first specified record to last record in buffer

After After NEVER (zeros) NEVER (zeros) 0

Table 4.24 Record Type 0065—Present Values


Field Description Min Max Notes

FLOAT32 Data for first channel. Repeat data field for each enabled LDP channel

•

•

•

4.39



Table 4.25 Record Type 0066—Meter Status



UINT8 Channel IA Status 0 = OK, 1 = Warn, 2 = Fail

UINT8 Channel IB Status 0 = OK, 1 = Warn, 2 = Fail

UINT8 Channel IC Status 0 = OK, 1 = Warn, 2 = Fail

UINT8 Channel IN Status 0 = OK, 1 = Warn, 2 = Fail

UINT8 Channel VA Status 0 = OK, 1 = Warn, 2 = Fail

UINT8 Channel VB Status 0 = OK, 1 = Warn, 2 = Fail

UINT8 Channel VC Status 0 = OK, 1 = Warn, 2 = Fail

UINT8 +3.3 V Power Supply Status 0 = OK, 1 = Warn, 2 = Fail

UINT8 +5 V Power Supply Status 0 = OK, 1 = Warn, 2 = Fail



UINT8 –1.25 V Power Supply Status 0 = OK, 1 = Warn, 2 = Fail

UINT8 –5 V Power Supply Status 0 = OK, 1 = Warn, 2 = Fail

UINT8 Clock Battery Status 0 = OK, 1 = Warn, 2 = Fail

UINT8 Mainboard Temperature Status 0 = OK, 1 = Warn, 2 = Fail

UINT8 RAM Status 0 = OK, 1 = Warn, 2 = Fail

UINT8 Program Memory Status 0 = OK, 1 = Warn, 2 = Fail

UINT8 Critical RAM Status 0 = OK, 1 = Warn, 2 = Fail

UINT8 NONVOL Memory Status 0 = OK, 1 = Warn, 2 = Fail

UINT8 CT Board Status 0 = OK, 1 = Warn, 2 = Fail

UINT8 PT Board Status 0 = OK, 1 = Warn, 2 = Fail

UINT8 Auxiliary Board Status 0 = OK, 1 = Warn, 2 = Fail

UINT8 Meter Enable Status 0 = OK, 1 = Warn, 2 = Fail

Table 4.26 Record Type 0067—LDP Data



UINT8 Status of the LDP record

UINT16 Year of the LDP record

UINT16 Julian day of the LDP record

UINT32 Tenths of milliseconds since midnight

FLOAT32 Data for first channel

•

•

•

•

Repeat data field for each enabled LDP channel

Repeat Status, date/time, and data fields for each LDP record

4.40


MeteringMetering Calculations

The status nibble unary flags have the following definitions (per C12.19-1997):

The SEL-734 reports this error if the meter overwrites old LDP data with new data during a response or if an operator issues an LDP C command.

Metering CalculationsThe information below details how the SEL-734 calculates various meter data. The SEL-734 samples analog values at 8000 times per second and performs a numerical approximation of the integral mathematical equations for voltage, current, and power. Where possible, these calculations reference the equivalent mathematical equations in IEEE 1459-2000.

Voltage and Current Magnitudes

Table 4.27 Status Nibble Definitions

Bit Meaning

0 Daylight-saving time is in effect during or at start of interval

1 Power fail within interval (missing data)

2 Clock reset forward during interval

3 Clock reset backwards during interval

4 Skipped interval (used for invalid or corrupted data)

5 TEST mode data

6 Data Overwrite (data erased during LDP read)

Table 4.28 Record Type 0068—SER Data



UINT16 Year of the SER

UINT16 Julian day of the SER

UINT32 Tenths of milliseconds since midnight

UINT16 SER data ENUM

• Repeat timestamp and data for each available SER

•

•

Table 4.29 Record Type 0069—LDP Error



CHAR[25] OVERWRITE OCCURRED String that contains a description of the error

where:N = Number of samples; N = 8000 for 1-second update

quantitiesx(n) = Array of periodic v or i samples corresponding to X

Xrms

x n( )[ ]2

0

N 1–∑⎝ ⎠

⎛ ⎞

N-------------------------------------=

4.41



Form 9 (3-element meter)Voltage: X = Va, Vb, or Vc

Current: X = Ia, Ib, or Ic

Form 5 (2-element meter)Voltage: X = Vab, or Vcb

Current: X = Ia, Ib, or Ic

Per-Phase Active Power (W)

This calculation is the numerical approximation of IEEE 1459-2000, 3.1.2.3.

Form 9 (3-element meter)x = a, b, or c

Form 5 (2-element meter)Per-phase values are not calculated for delta.

Average Calculations The SEL-734 calculates average 3-phase RMS values updated every 1 second where—

Imbalance Calculations

The SEL-734 calculates imbalance quantities using sequence values updated every 25 ms where—

Ibrms

Ia n( ) Ic n( )+( )2

0

N 1–∑

N---------------------------------------------------=

where:N = Number of samples

vx(n) = Array of periodic voltage samplesix(n) = Array of periodic current samples

Px

vx n( ) ix n( )•0

N 1–∑

N------------------------------------------=

NOTE: For Form 5 connections, V_AVG reports line-to-line voltages.

V_AVE VA_RMS VB_RMS VC_RMS+ +3

-------------------------------------------------------------------------------------=

I_AVE IA_RMS IB_RMS IC_RMS+ +3

------------------------------------------------------------------------------=

V_IMBV2_MAGV1_MAG------------------------ 100•=

I_IMBI2_MAGI1_MAG---------------------- 100•=

4.42



Three-Phase Active Power (W)

Form 9 (3-element meter)

P = Pa + Pb + Pc


This calculation is the numerical approximation of IEEE 1459-2000, 3.1.2.3, applied to the two-elements of a Form 5 meter.

Per-Phase Apparent Power (VA)

Sx = Vx • Ix

This calculation is the equivalent of IEEE 1459-2000, 3.1.28.


Form 5 (2-element meter)Per-phase values not calculated for delta

Three-Phase Apparent Power (VA)

Form 9 (3-element meter)S = Sa + Sb + Sc

This calculation provides arithmetic apparent power.


This calculation provides vector apparent power.

Per-Phase Reactive Power (VAR)

This calculation is the equivalent of IEEE 1459-2000, 3.1.2.15. Under sinusoidal conditions, this is equivalent to reactive power, VIsinθ. Under nonsinusoidal conditions, the value for Q will be larger due to the distortion power of the harmonics.


Form 5 (2-element meter)Per-phase values not calculated for delta

P

vab n( )0

N 1–

∑ ia n( )•

N----------------------------------------------

vbc n( )0

N 1–

∑ ic n( )•

N---------------------------------------------+=

S Vab Ia• Vab Ia–[ ] V+bc

Ic• Vbc Ic–[ ]∠∠=

Qx Sx2Px

2–=

4.43



Three-Phase Reactive Power (VAR)

Form 9 (3-element meter)Q = Qa + Qb + Qc


Energy Calculations The SEL-734 calculates energy by integrating power over time. This is accomplished using a numerical approximation of the integral. As an example, using active power, P, as described above, the SEL-734 calculates watthours by adding watthours for the most recent interval to the previously accumulated watthour value.

In the example above P can be a per-phase or polyphase quantity. Separate registers are used for bidirectional and 4-quadrant energy metering. These calculations are performed in a similar fashion for reactive and apparent power.

Q S2P

2–=

where:P = the active power measured over the time interval Δtn = the index for the most recent, non-overlapping interval Δt

Wh(n-1) = the accumulated energy from all prior intervalsΔt = the time interval in seconds, normally 1-second

Wh n( )xP tΔ•3600

--------------- Wh n 1–( ) watthours( )+=



Section 5R.Reference Manual

Time-of-Use

IntroductionTime-of-Use (TOU) Metering records energy consumption during specific periods of time. Therefore, SEL-734 users can bill consumption at different rates, based on a user-defined calendar. The SEL-734 records demand and energy consumption during different time periods based on Season, Day Type, and Time of Day.

The SEL-734 provides the following features for flexible TOU programming:

➤ Four Seasons

➤ Six Rates

➤ Ten Day Types

➤ Forty Rate Schedules

➤ Twenty-Year TOU Calendar

➤ Fifteen Self Reads

SettingsTo program the SEL-734 for TOU metering, create a TOU program using ACSELERATOR QuickSet® SEL-5030 Software. A TOU program defines the Calendar, Season Schedule, and Rate Schedule used by the TOU function.

To create a TOU program, read the existing settings from the meter and make the needed settings changes. You can also use ACSELERATOR QuickSet software to create new settings. The following pages describe TOU setup using ACSELERATOR QuickSet software.

After you create the TOU program, use the ACSELERATOR QuickSet software to download it to the meter.

5.2


Time-of-UseTOU Setup

TOU SetupUse the dialog box shown in Figure 5.1 to enable TOU and to establish TOU configuration for the SEL-734.

Setup Tab

Figure 5.1 Setup Page

Time-of-Use EnabledTime-Of-Use Enabled enables or disables TOU metering. Until you enable TOU, other TOU settings are not available.

Total CalculationUse Total Calculation to set the method the meter uses to calculate Total Energy. The options are:

➤ Delivered

➤ Received

➤ Delivered + Received

➤ Delivered – Received

Self-Read OptionsSelect Perform Self-Read On Manual Peak Demand Reset if you want the meter to perform a Self-Read when you issue a demand reset from the front panel.

Select Perform Self-Read After Manual Peak Demand Reset when you want the meter to perform a Self-Read a specified number of days after a demand reset. You must specify the number of days.

Available SeasonsSelect Available Seasons to set the number of seasons available for use in the TOU calendar.

5.3



Rate Schedules Tab

Figure 5.2 Rate Schedules Page

A Rate Schedule defines the rates to apply throughout a 24-hour day. A graphical representation of a day appears to the right of each Rate Schedules window. Rates (A to F) appear on the vertical axis, while time (00:00 to 24:00 hours) appears on the horizontal axis.

Create a New Rate ScheduleTo create a new Rate Schedule, click on the New button, or right-click in the Rate Schedules window and select New from the drop-down menu shown in Figure 5.3.

Figure 5.3 Schedule Drop-Down Menu

5.4



Delete a Rate Schedule

Figure 5.4 Deleting a Rate Schedule

1. Highlight the schedule you want to delete in the Rate Schedules list.

2. Click the Delete button or right-click and select Delete.

Rename a Rate ScheduleYou can rename a schedule by selecting it from the Rate Schedules list. Right-click on the schedule you want to change, select Rename from the menu, and type in the new name. User-defined names are limited to 20 characters.

Figure 5.5 Renaming a Rate Schedule

1. Select the Rate Schedule in the list of schedules.

2. Right-click and select Rename.

Modify a Rate ScheduleMake assignments to a schedule by highlighting the Rate Schedule you wish to change. The selected Rate Schedule appears as a chart on the right. Double-click (right or left) on the chart (see Figure 5.6) to insert a new rate.

➤ Double-click the left mouse button on the chart to insert a new rate.

➤ Each right-click of the mouse on an existing rate adds 1 minute.

➤ Each left-click of the mouse on an existing rate removes 1 minute.

➤ Keep the right mouse button depressed over an existing rate to expand the rate in 15-minute intervals until the mouse button is released or until the maximum 2400 hours interval limit is reached.

➤ Keep the left mouse button depressed over an existing rate to reduce the rate in 15-minute intervals until the mouse button is released or until the interval disappears.

5.5



➤ Right-click on a rate interval bar that has an interval of 5 minutes or less to delete that interval.

➤ Keep the left mouse button depressed on the chart location where you want the new rate to begin, drag to the right to specify the length of the rate you want, then release the left mouse button.

Figure 5.6 Modifying a Rate Schedule

Assign a Rate ScheduleOnce you have created all needed Rate Schedules, you must assign a specific schedule to each Day Type. You may use any schedule for any Day Type, during any season. To assign a Rate Schedule for an entire season (e.g., Season 1), you may click and drag the desired schedule from the list and drop it onto the name of the chosen season in the season table.

To assign a Rate Schedule for use on a specific Day Type during every season (e.g., Saturday), click and drag the desired Rate Schedule from the Rate Schedules list and drop it onto the chosen day in the table.

To assign a Rate Schedule to a Specific Day and Season, click and drag a Rate Schedule from the Schedules list and drop it onto the table entry corresponding to the specific day and season. Alternatively, place your mouse over the desired table entry and click the Edit button that appears on the screen. In the drop-down menu that appears, select the Rate Schedule you want.

Double-click toinsert new rate

5.6



Calendar Tab

Figure 5.7 Calendar Page

Each entry instructs the TOU program to perform a specific action on that day, such as defining the beginning and ending of seasons, assign alternate days (e.g., holidays), Self-Read days, and Demand Reset days, for that year.

Season changes, Day Type changes, Self-Reads, and Demand Resets execute at 00:00.001 on the day specified. Self-Reads occur before Demand Resets.

Add an Action to the CalendarTo add an action to the Calendar, select the year you wish to edit using the Display Year menu. Click and drag an action (Season Changes, Alternates, Self Read, Demand Reset, or Daylight Saving) from the top of the page, and drop the action icon onto the calendar date. You may also right-click on a calendar date and select New from the drop-down menu shown in Figure 5.8. The Calendar Entry Editor will appear as in Figure 5.9. Select the desired action and determine how you want this action to repeat.

5.7



Figure 5.8 Calendar Entry Drop-Down Menu

Figure 5.9 Calendar Entry Editor

Moving an Action on the CalendarDrag the action icon from one day to another. Drop the action icon on the day for which you want the action to occur.

Delete an Action from the CalendarSelect and drag an action icon off the calendar or into the recycle bin at the top of the form.

Edit an Action on the Calendar

Figure 5.10 Calendar Entry Editor

➤ Double-click on the calendar entry for the action you want to change

➤ Right-click on the calendar entry you want to change and select Edit

➤ Left-click on a Configure button to modify date patterns

5.8



Establish Quick Set Defaults

Figure 5.11 Quick Set Menu

Use the Quick Set options to return common TOU settings to factory defaults. To use a Quick Set option, perform the following:

1. Right-click on the calendar and select the Quick Set menu option.

2. Select the appropriate item from the Quick Set submenu (see Figure 5.11).

3. Click Yes when prompted.

TOU Register Data Click on the Meter and Control icon and select Time-of-Use from the HMI tree view to view all TOU Register Data. Use the Time-of-Use Registers drop-down menu to select the season data you want to view. The SEL-734 displays data in bar graph and text formats. See Figure 5.12.

Figure 5.12 TOU Data Page

5.9



TOU RegistersChoose which block of TOU registers you want to view. These blocks, available from the drop-down list, are as follows.

Present SeasonThis first block (the default) is for presently accumulated season data since the last season change.

Previous SeasonThis block provides data accumulated throughout the previous season.

Self-ReadsThere are 15 pairs of TOU register blocks that operate in the following manner:

➤ The Self-Read block provides TOU registers for the season in which the Self-Read occurs and shows accumulated data from the time of the last season change to the time of the Self-Read.

➤ The previous Self-Read block provides TOU registers for data accumulated throughout the previous season.

Data Export Use the Export button to create an Excel spreadsheet containing TOU register data and program setting information.

Billing Data Access to TOU Billing Data is available on any communications port using the Modbus protocol. Refer to Appendix F: Modbus RTU Communications Protocol for more information on accessing TOU data using the Modbus protocol. TOU Billing Data is also used as display points in the rotating display or for viewing using the front-panel main menu, via the front-panel HMI. Refer to Section 11: Front-Panel Operation for information on front-panel setup and use.

Appendix H: Analog Quantities lists all TOU billing quantities available in the SEL-734 and describes their usage.

Table 5.1 Available Time-of-Use Data (Sheet 1 of 3)

Rated Energy Block

Rate X MWH “Total”a

Rate X MVARH “Total”a

Rate X MVAH “Total”a

Rate X MWH Receiveda

Rate X MVARH Receiveda

Rate X MVAH Receiveda

Total MWH Received

Total MVARH Received

MWH “Total” at Demand Reset

MWH “Total” since Demand Reset

MVAH “Total” at Demand Reset

MVAH “Total” since Demand Reset

5.10



Rated Peak Demand Block

5 Max MW “Total” Peak Demands

5 Max MVAR “Total” Peak Demands

5 Max MVA “Total” Peak Demands

Rate X MW “Total” Peak Demanda

PF at Max MW “Total” Peak Demanda

PF at Rate X MW “Total” Peak Demanda

Rate X MVAR “Total” Peak Demanda

PF at Max MVAR “Total” Peak Demand

PF at Rate X MVAR “Total” Peak Demanda

Rate X MVA “Total” Peak Demanda

PF at Max MVA “Total” Peak Demand

PF at Rate X MVA “Total” Peak Demanda

Rated Peak Demand Time Block

Timestamps of 5 Max MW “Total” Peak Demands

Timestamps of 5 Max MVAR “Total” Peak Demands

Timestamps of 5 Max MVA “Total” Peak Demands

Timestamp of Rate X MW “Total” Peak Demanda

Timestamp of Rate X MVAR “Total” Peak Demanda

Timestamp of Rate X MVA “Total” Peak Demanda

Rated Cumulative Demand Block

MW “Total” Cumulative Peak Demand

Rate X MW “Total” Cumulative Peak Demanda

MVAR “Total” Cumulative Peak Demand

Rate X MVAR “Total” Cumulative Peak Demanda

MVA “Total” Cumulative Peak Demand

Rate X MVA “Total” Cumulative Peak Demanda

Demand Reset Block

Max MW “Total” Peak Demand at last demand reset

Max MVAR “Total” Peak Demand at last demand reset

MW “Total” Peak Demand at Min Total PF at last demand reset

MW “Total” Peak Demand at Min Total PF since last demand reset

Min “Total” PF at last demand reset

Min “Total” PF since last demand reset

Average “Total” PF at last demand reset

Average “Total” PF since last demand reset

Number of demand resets


5.11


Time-of-UseTOU Glossary

TOU GlossaryTOU Register Data Contains all registers included in a Rate X register set for each of the rates you

have defined. These are the data necessary to produce a bill for the consumer.

Cumulative Demand The sum of the peak demand readings after each demand reset during the same billing period. At each demand reset, the meter adds the peak demand from the most recent billing period to the previously accumulated total of all peak demands.

Day Type A day (24 hours) that has a specific rate assigned for each season through the Rate-Schedule table. Day Types are Monday, Tuesday, Wednesday, Thursday, Friday, Saturday, Sunday, Alternate 1, Alternate 2, and Alternate 3. These represent the typical days of the week and three alternate days for holidays or special occasions.

Five Maximum MW/MVAR/MVA “Total” Demands

The five maximum megawatt/VAR/volt-ampere demand values recorded since the last demand reset. The values are nonrated and are listed from highest to lowest. The meter uses the Total Calculation setting to calculate these registers and includes timestamps for each of the five maximum demands. The maximum demand includes the coincident power factor.

MWH/MVAH Total At/Since Demand Reset

Each demand reset resets to zero the values the meter has collected since the previous demand reset. See Figure 5.13.

Figure 5.13 Total At/Since Demand Reset

Demand Reset Timestamp Block

Timestamp of Max MW “Total” Peak Demand at last demand reset

Timestamp of Max MVAR “Total” Peak Demand at last demand reset

Timestamp of Min “Total” PF at last demand reset

Timestamp of Min “Total” PF since last demand reset

Timestamp of last demand reset

a X = A through F.


MWH Total at Demand Reset

MWH Total since Demand ResetPresentTime

DemandReset

DemandReset

DemandReset

Time

MWH

5.12



MW/MVAR “Total” Cumulative Demand

The sum of the peak demand between each demand reset without regard to rate. See Figure 5.14.

Figure 5.14 Peak Cumulative Demand

Rate X MW/MVAR “Total” Cumulative Demand

Where X = A through F. Similar to the definition for MW/MVAR “Total” Cumulative Demand, except that the meter sums peaks according to rate.

Rate Schedule A schedule spanning one day (24 hours) that specifies the Rate X register set into which the meter records energy and maximum demand data. For example, the meter records data from midnight until 07:59 into Rate A registers. The meter will record data in this manner until midnight, when the rate schedule for the following day applies.

Rate X MWH, MVARH, MVAH Received

Where X = A through F. The number of received megawatt/VAR/volt-ampere hours the meter records during periods defined for a given Day Type within a given season. These values constitute received quantities only.

Rate X MWH, MVARH, MVAH “Total”

Where X = A through F. The number of megawatt/VAR/volt-ampere hours the meter records during periods defined for a given Day Type within a season. The meter uses the Total Calculation setting to calculate these registers.

Rate X MW/MVAR/MVA “Total” Peak Demand

Where X = A through F. The Peak Total demand recorded at each rate since the last demand reset.

The meter uses the Total Calculation setting to calculate these registers, and includes timestamps and coincident power factors.

Rated Demand or Energy

The value that the TOU program in the SEL-734 stores for each rate schedule defined in the ACSELERATOR QuickSet Time-Of-Use setting window.

Season A consecutive period delimited by one-day boundaries such as January 1–March 31. You must define one or more seasons that span an entire calendar year and specify which rate schedule applies to each Day Type. The seasons typically repeat for each year of the 20-year calendar. Use the TOU calendar to specify seasons.

Peak Demand 1

Peak Demand 2

PresentTime

DemandReset 1

DemandReset 2

Time

Cumulative Demand = Peak Demand 1 + Peak Demand 2

5.13



Self-Read The SEL-734 copies and stores the present values in demand and energy registers.

Total Calculation The meter calculates a total energy value according to the following Total Calculation setting options:

➤ Delivered

➤ Received

➤ Delivered + Received

➤ Delivered – Received

Total MWH, MVARH Received

The total number of received MWH/MVAR hours recorded during this season. These energy values are unrated registers, accumulated without regard to rate.



Section 6Power Quality and Event Analysis

OverviewThe SEL-734 Meter offers three styles of event reports:

➤ Waveform Capture Event Reports

➤ Sequential Events Recorder (SER) Report

➤ Voltage Sag/Swell/Interruption (VSSI) Report

Waveform Capture Event Reports

Waveform capture, also known as oscillography, allows the SEL-734 to record the voltage and current waveforms associated with programmable trigger conditions, such as a voltage interruption. The sample rate and duration of the waveform capture are predetermined using Event Report settings. The supported sample rates are 1 kHz and 8 kHz. Use of the 8 kHz sample rate captures harmonic content up to the 50th order. The 1 kHz sample rate contains harmonic content up to the 7th order.

The duration of the waveform capture can be set from 0.25 to 10 seconds. Each waveform capture will contain at least 4 cycles of pretrigger data. The number of waveform captures stored in memory will be determined by the sample rate, duration, and the SEL-734 hardware configuration. The meter stores the most recent waveform capture in nonvolatile memory. If more waveform captures are triggered, the latest waveform capture overwrites the oldest waveform capture.

The SEL-734 provides an option to generate 15-cycle at 16-samples per cycle event reports. These reports are filtered to provide fundamental-only waveforms—harmonics and interharmonics are filtered out. These reports show information for 15 continuous cycles—4 cycles of prefault data followed by 11 cycles of fault data. The event reports contain date, time, currents, voltages, frequency, and Meter Word bits.

Automated Event Report Retrieval

The ACSELERATOR Report Server software, SEL-5040, automatically retrieves, databases, and displays SEL-734 Event Reports. The Report Server software integrates with the SEL-734, which automatically sends new event reports to the SEL-5040 software allowing near instantaneous display of event waveforms. For additional information on the ACSELERATOR Report Server SEL-5040 software, please contact your SEL Sales Representative.

Sequential Events Recorder (SER) Report

The meter adds lines in the sequential events recorder (SER) report for a change of state of a programmable condition. The SER lists date and time-stamped lines of information each time a programmed condition changes state. See Figure 6.4 for an example SER report.

6.2


Power Quality and Event AnalysisEvent Reports

Voltage Sag/Swell/ Interruption (VSSI) Report

The VSSI report captures voltage disturbances and displays summary or detailed information per IEC 61000-4-30 and CBEMA/ITIC. The SEL-734 reports VSSI disturbances through the SER, SEL ASCII, ACSELERATOR QuickSet and DNP3 interfaces. The ACSELERATOR QuickSet® SEL-5030 Software interface includes graphical representation of disturbances with additional analysis options.

Flicker Meter The SEL-734P reports flicker data through the MET FL command, front panel, display points, DNP, Modbus®, analog outputs, ACSELERATOR QuickSet HMI, and the load profile (LDP) recorder. The short-term flicker value, PST, is available in 10-minute intervals, and the long-term flicker value, PLT, is available in 2-hour intervals.

Event ReportsStandard Event Report Triggering

The meter triggers (generates) a standard event report when any of the following occur:

➤ Programmable SELOGIC® control equation settings ERn (n = 1–3) asserts to logical 1

➤ TRI (Trigger Event Reports) serial port command executed

Programmable SELOGIC Control Equation Settings ERnThe programmable SELOGIC control equation event report trigger settings ER1, ER2, and ER3 are set to trigger standard event reports. When setting ERn sees a logical 0 to logical 1 transition, it generates an event report (if the SEL-734 is not already generating a report that encompasses the new transition). The factory setting for SEL-734 meters is listed below:

ERn = 0

TRI (Trigger Event Report)The sole function of the TRI serial port command is to generate standard event reports, primarily for testing purposes.

See Section 10: Communications and Section 11: Front-Panel Operation for more information on the TRI (Trigger Event Report) and PUL (Pulse Output Contact) commands.

Standard Event Report Summary

Each time the meter generates a standard event report, it also generates a corresponding event summary (see Figure 6.1). Event summaries contain the following information:

➤ Date and time when the event was triggered

➤ System frequency at the front of the event report

➤ Cause of event (e.g., TRI, ER)

➤ Front-panel LED status (targets)

The meter includes the event summary in the standard event report. The identifiers, date, and time information is at the top of the standard event report, and the other information follows at the end.

6.3




# DATE TIME EVENT FREQ TARGETS

1 04/10/03 14:18:53.176 TRIG 59.99 000001Example Event Summary

Figure 6.1 Standard Event Report Summary

The meter sends event summaries to any serial ports with setting AUTO = Y each time an event triggers.

The latest event summaries are stored in nonvolatile memory and are accessed by the HIS (Event Summaries/History) command.

Retrieving Full-Length Standard Event Reports

Use the EVE command to retrieve standard event reports. There are several options for customizing the report format. The general command format is:

EVE [n L R C]

See Table 6.1 for examples of EVE commands.

The EVE command, without the L option, provides the following four sections:➤ Current, voltage, frequency

➤ Meter elements

➤ Event summary

➤ Group, SELOGIC® control equations, and global settings

The EVE command, with the L option, provides only current and voltage values.

If you request an event report that does not exist, the meter responds:

Invalid Event

where:n = If n is 1 to 9999: n is the event number. Defaults to 1 if not

listed, where 1 is the most recent event.If n is 10000 to 99999: n is the event serial number.

L or R = Specifies raw (unfiltered) analog data at the sample rate specified by SRATE (1 or 8 kHz) and the duration specified by LER.

C = Display the report in Compressed ASCII format.

Table 6.1 Example EVE Commands

Serial Port Command Description

EVE Display the most recent event report at 16 samples-per-cycle resolution, fundamental frequency only.

EVE 2 Display the second event report at 16 samples-per-cycle resolution, fundamental frequency only.

CEV 2 / EVE C 2 Display the second report in Compressed ASCII format at 16 samples-per-cycle resolution, fundamental frequency only.

EVE L / EVE R Display the most recent report at 1 or 8 kHz resolution; analog data are unfiltered (raw).

CEV R / EVE C R Display the most recent report 1 or 8 kHz resolution in Compressed ASCII format; analog data are unfiltered (raw).

6.4



Compressed ASCII Event Reports

The SEL-734 provides Compressed ASCII event reports to facilitate event report storage and display. The SEL-2030 Communications Processor, the SEL-5601 Analytic Assistant software, and the ACSELERATOR QuickSet® SEL-5030 Software take advantage of the Compressed ASCII format. Use the EVE C command or CEVENT command to display Compressed ASCII event reports. Use the EVE C R or CEVENT R commands to display raw event reports in the Compressed ASCII format. See Table C.2 for further information.

Comtrade Format Event Reports

The SEL-734 provides the raw event report in Comtrade format for use with SEL-5601 and other Comtrade viewers. The CTR command displays the raw event report in Comtrade format, meeting the International Standard for Comtrade Format for Transient Data Exchange (COMTRADE) for power systems (IEC 60255-24). The user may generate files for both analog and digital signals, or for solely analog signals based on command format. Use the CTR command with the following format to display or save these records.

CTR [n] x [y]

Each Comtrade record consists of a configuration and a data file. To save these files, capture the configuration file using the CTR C or CTR C A command, saving it with file extension .cfg. Save the data file in a similar manner, using the CTR D or CTR D A command to retrieve the file and save it using the .dat extension.

Configuration and data file names should be the same with extensions .cfg and .dat, respectively.

The CTR command is available at Access Level 1 and above (see Command Explanations on page 10.14).

Compressed Comtrade Format Event ReportsThe SEL-734 provides raw event reports in a compressed format, which is compressed using the RFC 1950 method and includes ZLIB headers. Each compressed file is saved as HR_xxxxx.ZDAT in the EVENTS directory, where xxxxx is the event serial number. Use the FIL READ command to retrieve a Compressed Comtrade Data File. For example, to retrieve compressed Comtrade file event with serial number 10001, enter FIL READ EVENTS\HR_10001.ZDAT <Enter>.

Standard Event Reports With Meter Form 5When you order the meter as a Form 5, the event report voltage columns reflect the signals applied to meter terminals VA-N, VB-N, VC-N, even though the meter is configured for an open-delta PT connection (see Figure 2.9). If the meter is properly wired, the value shown in column VB should be at or near 0 kV, because input terminal VB is tied to terminal N. Column VA should reflect power system voltage VAB, and column VC should reflect power system voltage VCB (or –VBC).

where:n = If n is 1 to 9999: n is the event number. Defaults to 1 if not

listed, where 1 is the most recent event.If n is 10000 to 99999: n is the event serial number.

x = either C (configuration) or D (data)y = either A or blank. A designates analog data only. If left

blank, both analog and digital data are generated.

6.5



Auto Messages The SEL-734 can automatically send unsolicited text messages called Auto Messages over the serial ports to other devices. These messages include device power-on or reset, event triggers, and self-test warnings or failures. To enable Auto Messages, select Y in the serial port setting Send Auto Messages to Port. Figure 6.2 shows a typical Auto Message response when the meter triggers an event report.

Figure 6.2 Typical Auto Message Response

Clearing Standard Event Report Buffer

The HIS C command clears the event summaries and corresponding standard event reports from nonvolatile memory. See Section 10: Communications for more information on the HIS (Event Summaries/History) command.

Standard Event Report Column Definitions

Refer to the example event report in Figure 6.3 to view event report columns. This example event report displays rows of information each 1/16-cycle and was retrieved with the EVE command.

The columns contain ac current, ac voltage, and frequency information.

Current, Voltage, and Frequency ColumnsTable 6.2 summarizes the event report current, voltage, and frequency columns.

Some of the column definitions are different for wye-connected PT applications (Meter Form 9) and delta-connected PT applications (Meter Form 5). These differences are noted in Table 6.2. Figure 6.3 shows a wye-connected example event report.

Table 6.2 Standard Event Report Current, Voltage, and Frequency Columns (Sheet 1 of 2)

Column Heading Definition

IA Current measured by channel IA (secondary A)

IB Current measured by channel IB (secondary A)

IC Current measured by channel IC (secondary A)

IN Current measured by channel IN (secondary A)

VA Voltage measured by channel VA (secondary V, Form 9)

VB Voltage measured by channel VB (secondary V, Form 9)

VC Voltage measured by channel VC (secondary V, Form 9)

VAB Power system phase-to-phase voltage VAB (secondary V, Form 5)a

VBC Power system phase-to-phase voltage VBC (secondary V, Form 5)a

6.6


Power Quality and Event AnalysisExample Standard 15-Cycle Event Report

Note that the ac values change from plus to minus (–) values in Figure 6.3, indicating the sinusoidal nature of the waveforms.

Example Standard 15-Cycle Event ReportThe following example standard 15-cycle event report in Figure 6.3 (from a SEL-734 Form 9) also corresponds to the example sequential events recorder (SER) report in Figure 6.4.

An arrow (>) in the column following the Freq column identifies the “trigger” row. This row corresponds to the Date and Time values at the top of the event report.

VCA Power system phase-to-phase voltage VCA (secondary V, Form 5)a

Freq Frequency of channel VA (or VC if VA is not present; Hz)

a When Form 5 and meter terminals VA, VB, and VC are properly wired, as shown in Figure 2.9, the filtered event report voltage values are determined as follows:

- VAB reflects the measured value from meter terminals VA-N- VBC reflects the measured value from meter terminals VC-N rotated by 180° (VBC = –VCB)- VCA reflects the value derived from the subtraction of the measured value from meter

terminals VA-N from the measured value from meter terminals VC-N (VCA = VCB – VAB)

Table 6.2 Standard Event Report Current, Voltage, and Frequency Columns (Sheet 2 of 2)

Column Heading Definition

=>>EVE <Enter>


FID=SEL-734-X2xx-V0-Z011010-D20080710 CID=0728

Currents (Amps Sec) Voltages (Volts Sec) IA IB IC IN VA VB VC Freq[1] 0.35 -2.33 1.96 -0.00 59.84 -122.52 62.08 59.98 1.28 -2.51 1.22 -0.00 96.35 -113.69 17.01 59.98 2.00 -2.30 0.28 0.00 118.20 -87.61 -30.61 59.98 2.43 -1.75 -0.69 0.00 122.09 -48.25 -73.55 59.98 2.48 -0.93 -1.56 0.00 107.44 -1.57 -105.30 59.98 2.16 0.03 -2.19 0.00 76.47 45.35 -121.08 59.98 1.51 0.99 -2.49 0.00 33.86 85.43 -118.48 59.98 0.63 1.80 -2.41 0.00 -13.95 112.58 -97.87 59.98 -0.35 2.33 -1.97 0.00 -59.71 122.65 -62.34 59.98 -1.28 2.51 -1.22 0.00 -96.44 114.01 -17.23 59.98 -2.01 2.31 -0.29 0.00 -118.50 87.96 30.56 59.98 -2.44 1.75 0.69 0.00 -122.51 48.45 73.75 59.98 -2.49 0.93 1.57 0.00 -107.84 1.51 105.74 59.98 -2.17 -0.03 2.20 -0.00 -76.71 -45.69 121.63 59.98 -1.51 -1.00 2.50 -0.00 -33.86 -85.94 118.97 59.98 -0.63 -1.81 2.42 -0.00 14.15 -113.10 98.17 59.98

• • •

[5] 0.36 -2.34 1.97 0.00 60.15 -123.00 62.23 59.98> 1.29 -2.52 1.22 0.00 96.81 -114.08 16.94 59.98 2.02 -2.31 0.28 0.00 118.70 -87.78 -30.91 59.98 2.44 -1.75 -0.70 0.00 122.48 -48.13 -74.02 59.98 2.49 -0.92 -1.57 0.00 107.59 -1.17 -105.80 59.98 2.16 0.04 -2.20 0.00 76.32 45.92 -121.44 59.98 1.50 1.00 -2.50 0.00 33.46 85.93 -118.55 59.98 0.62 1.80 -2.41 0.00 -14.43 112.79 -97.59 59.98 -0.36 2.33 -1.96 -0.00 -60.05 122.47 -61.83 59.98 -1.28 2.50 -1.21 -0.00 -96.49 113.54 -16.74 59.98 -2.01 2.30 -0.28 -0.00 -118.26 87.40 30.85 59.98 -2.43 1.74 0.69 -0.00 -122.06 47.99 73.74 59.98 -2.48 0.92 1.56 -0.00 -107.33 1.29 105.43 59.98

See Figure 6.1

Firmware IdentifierFirmware Checksum Identifier

one cycle of data

[cycles 2–4 not shown in this example.]

Trigger Row

6.7


Power Quality and Event AnalysisExample Standard 15-Cycle Event Report

Figure 6.3 Example Standard 15-Cycle Event Report 1/16-Cycle Resolution (Wye-Connected PTs)

-2.16 -0.04 2.20 -0.00 -76.30 -45.64 121.13 59.98 -1.50 -0.99 2.49 -0.00 -33.64 -85.67 118.44 59.98 -0.62 -1.80 2.41 -0.00 14.19 -112.75 97.75 59.98

• • •

Control ElementsRem Ltch SELogic Variable 1111111 1111111 11111111234567890123456 1234567890123456 1234567890123456[1]................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................ ................

• • •

Communication Elements

TMB RMB TMB RMB RRCLA A B B OBBB1357 1357 1357 1357 KAAO2468 2468 2468 2468 DDK[1].... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... .... ....

• • •

Event: TRIG Frequency: 59.98Targets: 0001111

Meter Settings:

MID :=FEEDER 1 TID :=STATION A EDEM := BLOK EPRED := N ESSI := Y ETLLC := N EKYZ := N CTR := 10.0000 CTRN := 10.0000 PTR := 10.0000 FLTBLK :=027P1P := 80

PARTNO=0734P0931A1216E5X6A3A=>>



See Figure 6.1


6.8


Power Quality and Event AnalysisSequential Events Recorder (SER) Report

Sequential Events Recorder (SER) ReportSee Figure 6.4 for an example SER report.

SER Triggering The meter triggers (generates) an entry in the SER report for a change of state of any one of the elements listed in the SER1, SER2, and SER3 trigger settings. The factory default settings are:

SER1 = NA

SER2 = NA

SER3 = NA

The elements are Meter Word bits referenced in Table 9.3. The meter monitors each element in the SER lists every processing interval (25 ms). If an element changes state, the meter time-tags the changes in the SER.

The meter adds a message to the SER to indicate power up, daylight-saving time or other time changes, or settings change conditions.

Each entry in the SER includes SER row number, date, time, element name, and element state.

Making SER Trigger Settings

Enter as many as 24 element names in each of the SER settings via the SET R command. See Table 9.3 for references to valid Meter element (Meter Word bit) names. See the SET R command in Table 9.1 and corresponding SEL-734 Settings Sheets at the end of Section 9: Settings. Use commas to delimit the elements. For example, if you enter setting SER1 as:

SER1 = IN101 SV01 FAULT

The meter displays the setting as:

SER1 = IN101, SV01, FAULT

The meter can monitor as many as 72 elements in the SER (24 in each of SER1, SER2, and SER3).

The meter triggers a row in the Sequential Events Recorder (SER) event report for any change of state in any one of the elements listed in the SER1, SER2, or SER3 trigger settings. The meter retains a minimum of 21,000 of the most recent SER entries in nonvolatile memory.

Retrieving SER Reports

Row 1 is the most recently triggered row. View the SER report by date or SER row number, as outlined in the examples in Table 6.3.

The date entries in the above example SER commands are dependent on the Date Format setting DATE_F.

Table 6.3 Example SER Serial Port Commands

Example SER Serial Port Command

Response

SER The SEL-734 returns all SER data.

SER 17 The SEL-734 returns the most recent 17 SER rows.

SER 10 33 or SER 33 10 The SEL-734 returns SER rows 10–33 or 33–10 in chronological or reverse chronological order, respectively.

SER 1/1/2009 The SEL-734 returns all SER data recorded after 1/1/2009.

SER 1/1/2009 2/1/2009 or SER 2/1/2009 1/1/2009

The SEL-734 returns all SER data recorded between 1/1/2009 and 2/1/2009 in chronological or reverse chronological order, respectively.

6.9


Power Quality and Event AnalysisExample Sequential Events Recorder (SER) Report

If the requested SER event report rows do not exist, the meter responds:

No SER Data

Clearing the SER Report

Clear the SER report from nonvolatile memory with the SER C command, as shown in the following example:

=>SER C <Enter>

Clear the SERAre you sure (Y/N)? Y <Enter>Clearing Complete

Example Sequential Events Recorder (SER) ReportFigure 6.4 is an example sequential events recorder (SER) report (from a Model 0734ES2-XX Meter).

=>>SER <Enter>


FID=SEL-734-X119-V0-Z001001-D20030403 CID=8AD8

# Date Time Element State

21 04/10/03 11:02:25.901 DFAULT Asserted 20 04/10/03 11:02:25.901 FAULT Asserted 19 04/10/03 11:02:25.926 FAULT Deasserted 18 04/10/03 11:02:32.551 FAULT Asserted 17 04/10/03 11:02:32.601 FAULT Deasserted 16 04/10/03 11:03:32.601 DFAULT Deasserted 15 04/10/03 12:50:12.751 Settings changed 14 04/10/03 12:51:08.376 DFAULT Asserted 13 04/10/03 12:51:08.376 FAULT Asserted 12 04/10/03 12:51:08.401 SAGB Asserted 11 04/10/03 12:51:08.426 SAGC Asserted 10 04/10/03 12:51:08.426 SAGA Asserted 9 04/10/03 12:51:08.501 FAULT Deasserted 8 04/10/03 12:51:24.202 FAULT Asserted 7 04/10/03 12:51:24.251 FAULT Deasserted 6 04/10/03 12:52:06.026 Settings changed 5 04/10/03 12:52:15.626 OUT101 Asserted 4 04/10/03 12:52:15.651 OUT101 Deasserted 3 04/10/03 12:52:24.251 DFAULT Deasserted 2 04/10/03 12:52:27.976 OUT401 Asserted 1 04/10/03 12:52:28.001 OUT401 Deasserted

=>>

Figure 6.4 Example Sequential Events Recorder (SER) Report

The SER report rows in Figure 6.4 are explained in the following text, numbered in correspondence to the # column.

Table 6.4 Sequential Events Recorder Explanation

SER Row No. Explanation

20, 21 Meter word FAULT asserted causing DFAULT to assert.

19 Meter word FAULT deasserted (see FAULT logic).

15 A setting change occurred in the meter.

10, 11, 12 Meter words SAGA, SAGB, SAGC asserted indicating a voltage sag on the system.

4, 5 OUT101 asserted and deasserted based on the SELOGIC equations.

2, 1 OUT401 asserted and deasserted based on the SELOGIC equations.

6.10


Power Quality and Event AnalysisVoltage Sag/Swell/Interruption (VSSI) Report

Voltage Sag/Swell/Interruption (VSSI) Report

Figure 6.5 ACSELERATOR QuickSet VSSI Report With CBEMA/ITIC and Disturbance Analysis

See Figure 6.7 and Figure 6.8 for example VSSI reports.

The VSSI report captures voltage disturbances and displays summary or detailed information per IEC 61000-4-30 and CBEMA/ITIC. The SEL-734 reports VSSI disturbances through the SER, SEL ASCII, ACSELERATOR QuickSet, and DNP3 interfaces. The ACSELERATOR QuickSet software interface includes graphical representation of disturbances with additional analysis options as shown in Figure 6.5.

The SEL-734 records VSSI data using an adaptive sampling rate algorithm that maximizes the number of disturbances that the meter can store. Given an average 3-second disturbance, the SEL-734 will capture at least 60 independent disturbances and a minimum of 11,000 detailed entries. Sampling rates include Fast recording at 4 samples per cycle, medium recording at 1 sample per cycle, slow recording at 1 sample per 64 cycles, and daily at 1 sample per day.

VSSI SettingsThe group setting ESSI = Y enables the voltage sag/swell/interruption reporting. The VBASE setting defines the initial phase-to-neutral voltage applied to Form 9 connections, and phase-to-phase voltage applied to Form 5 connections. Set AVG_TIME to a time between 1 and 10 minutes to calculate a dynamic VBASE as the average RMS phase voltage over the time period defined by AVG_TIME. After VSSI initialization, VBASE for each phase is set to the VBASE setting. When the AVG_TIME period elapses, VBASE for each phase is calculated as the 1-second average RMS voltage over the period.

Set AVG_TIME to OFF to disable the dynamic VBASE feature. The VINT, VSAG, and VSWELL trigger thresholds define the percentage of VBASE at which the meter records a disturbance. Hysteresis settings, VINTHYS, VSAGHYS, and VSWELHYS define the percentage above the trigger thresholds at which the VSSI report stops recording.

6.11



VSSI InitializationThe following conditions must be met before the VSSI function will capture voltage disturbances:

➤ The phase voltage is greater than 25V

➤ The FAULT Meter Word Bit is deasserted.

➤ Ten seconds have elapsed meeting these conditions.

VSSI Summary ReportThe VSSI report in the ACSELERATOR QuickSet HMI interface or the SSI S SEL ASCII command will display summary VSSI reports as shown in Figure 6.6. Upon a voltage disturbance, the VSSI will report the event type, date, time, duration, voltages as a percentage of VBASE, and VBASE in compliance with IEC 61000-4-30. See the Command Summary (Table 10.23 on page 10.34) for a full list of VSSI commands.

f

Figure 6.6 Example VSSI Response in ACSELERATOR QuickSet

At the end of each disturbance, the VSSI summary reports the following information:

➤ List of events in chronological order.

➤ Event type➢ DIP

➢ SWELL

➢ INT

➢ TRIG

➤ Date and time the event started.

➤ Event duration in hhh:mm:ss.sss

➤ Minimum and maximum voltage magnitude per IEC 61000-4-30

➤ One of the three CBEMA/ITIC events regions➢ Prohibited region (PR)

➢ No damage region (ND)

➢ Safe function region (SR)

VSSI Detailed ReportThe detailed VSSI report includes a point by point record of each VSSI value that is useful for graphing data post-disturbance. The VSSI report in the ACSELERATOR QuickSet HMI interface or the SSI SEL ASCII commands will display detailed VSSI reports. Table 6.5 and Table 6.6 describe the meaning of the detailed VSSI status columns. See the Command Summary (Table 10.23 on page 10.34) for a full list of VSSI commands.

6.12



The VSSI recorder archives the following information:➤ Currents Ia, Ib, Ic, Ig, and In as a percentage of the nominal

current rating (shown in the report heading)

➤ Voltages VA, VB, and VC as a percentage of the VBASE quantity (Meter Form 9)

➤ Voltages VAB, VBC, and VCA as a percentage of the VBASE quantity (Meter Form 5)

➤ State of the voltage sag/swell/interruption Meter Word bits, by phase

➤ Trigger status

➤ Recorder status

See Figure 6.7 for an example voltage sag/swell/interruption (VSSI) report.

The voltage sag/swell/interruption (VSSI) report in Figure 6.7 shows a voltage sag on A-phase (meter input IN is not connected).

Table 6.5 Element Status Columns

Symbol Meaning (for Column A, B, or C)

Meter Form 9

Column A represents p = A

Column B represents p = B

Column C represents p = C

Meter Form 5

Column A represents pp = AB

Column B represents pp = BC

Column C represents pp = CA

. No VSSI bits asserted for phase p No VSSI bits asserted for phases pp

O Overvoltage (SWp asserted) Overvoltage (SWpp asserted)

U Undervoltage (SAGp asserted) Undervoltage (SAGpp asserted)

I Interruption (INTp asserted; SAGp asserted, unless setting VSAG = OFF)

Interruption (INTpp asserted; SAGpp asserted, unless setting VSAG = OFF)

Table 6.6 Status VSSI Column

Symbol Meaning (Action) Duration

R Ready Single entry

P Predisturbance (4 samples per cycle). Always signifies a new disturbance.

12 samples (3 cycles)

F Fast recording mode (4 samples per cycle) Varies. At least one VSSI element must be asserted.

E End (postdisturbance at 4 samples per cycle) Up to 16 samples (4 cycles). No VSSI elements asserted.

M Medium recording mode (one sample per cycle) Maximum of 176 cycles

S Slow recording mode (one sample per 64 cycles) Maximum of 4096 cycles

D Daily recording mode (one sample per day, just after midnight)

Indefinite

X Data overflow (single entry that indicates that data were lost prior to the present entry)

Single entry

NOTE: Any current or voltage value greater than 999 percent will be replaced by “$$$” in the VSSI report.

6.13



=>>SSI <Enter>Processing.


FID=SEL-734-X345-V0-Z101101-D20100210 CID=BBF6

I nom. A B C G = 5 Amp N = 5 Amp Ph-A Ph-B Ph_C

Current(%I nom.) Vbase Volt Vbase Volts Vbase Volts Ph ST# Date Time Ia Ib Ic Ig In (Vsec) %Vbase (Vsec) %Vbase (Vsec) %Vbase ABC

478 01/17/10 05:29:53.249 400.9 400.0 398.7 3.3 0.0 120.00 102.2 120.00 102.2 120.00 102.3 ... P477 01/17/10 05:29:53.253 401.0 399.8 398.7 3.3 0.0 120.00 102.3 120.00 102.2 120.00 102.3 ... P476 01/17/10 05:29:53.257 400.8 399.9 398.8 3.3 0.0 120.00 102.2 120.00 102.2 120.00 102.3 ... P475 01/17/10 05:29:53.262 400.9 399.9 398.7 3.2 0.0 120.00 102.2 120.00 102.2 120.00 102.3 ... P474 01/17/10 05:29:53.266 401.0 399.8 398.8 3.2 0.0 120.00 102.3 120.00 102.2 120.00 102.4 ... P473 01/17/10 05:29:53.270 400.7 400.0 398.9 3.2 0.0 120.00 102.2 120.00 102.2 120.00 102.4 ... P472 01/17/10 05:29:53.274 400.8 400.0 398.8 3.3 0.0 120.00 102.2 120.00 102.2 120.00 102.3 ... P471 01/17/10 05:29:53.278 401.0 399.9 398.7 3.3 0.0 120.00 102.2 120.00 102.2 120.00 102.3 ... P470 01/17/10 05:29:53.282 400.8 400.0 398.8 3.3 0.0 120.00 102.2 120.00 102.2 120.00 102.3 ... P469 01/17/10 05:29:53.287 400.9 399.8 398.7 3.1 0.0 120.00 102.2 120.00 102.2 120.00 102.3 ... P468 01/17/10 05:29:53.291 401.0 399.7 398.8 3.1 0.0 120.00 102.4 120.00 102.2 120.00 102.3 ... P467 01/17/10 05:29:53.292 400.8 400.0 398.9 3.1 0.0 120.00 66.2 120.00 102.2 120.00 102.3 ... P466 01/17/10 05:29:53.292 400.8 400.0 398.7 3.4 0.0 120.00 0.0 120.00 102.2 120.00 102.3 I.. F465 01/17/10 05:29:53.303 401.0 399.8 398.7 3.4 0.0 120.00 0.0 120.00 102.1 120.00 102.3 I.. F464 01/17/10 05:29:53.307 400.8 400.0 398.8 3.4 0.0 120.00 0.0 120.00 102.2 120.00 102.4 I.. F463 01/17/10 05:29:53.312 400.9 400.0 398.7 3.3 0.0 120.00 0.0 120.00 102.2 120.00 102.3 I.. F462 01/17/10 05:29:53.316 401.0 399.8 398.7 3.3 0.0 120.00 0.0 120.00 102.2 120.00 102.3 I.. F461 01/17/10 05:29:53.320 400.8 399.9 398.8 3.3 0.0 120.00 0.0 120.00 102.2 120.00 102.4 I.. F460 01/17/10 05:29:53.324 400.9 399.9 398.8 3.4 0.0 120.00 0.0 120.00 102.2 120.00 102.3 I.. F459 01/17/10 05:29:53.328 400.9 399.9 398.7 3.4 0.0 120.00 0.0 120.00 102.2 120.00 102.3 I.. F458 01/17/10 05:29:53.332 400.7 400.1 398.8 3.4 0.0 120.00 0.0 120.00 102.2 120.00 102.4 I.. F457 01/17/10 05:29:53.337 401.0 399.8 398.7 3.1 0.0 120.00 0.0 120.00 102.2 120.00 102.3 I.. F456 01/17/10 05:29:53.341 401.1 399.7 398.8 3.1 0.0 120.00 0.0 120.00 102.2 120.00 102.3 I.. F455 01/17/10 05:29:53.345 400.9 400.0 398.8 3.1 0.0 120.00 0.0 120.00 102.2 120.00 102.3 I.. F454 01/17/10 05:29:53.349 400.8 400.0 398.8 3.4 0.0 120.00 0.0 120.00 102.2 120.00 102.4 I.. F453 01/17/10 05:29:53.353 401.0 399.8 398.7 3.4 0.0 120.00 0.0 120.00 102.1 120.00 102.4 I.. F452 01/17/10 05:29:53.357 400.8 400.0 398.7 3.4 0.0 120.00 0.0 120.00 102.2 120.00 102.3 I.. F451 01/17/10 05:29:53.362 401.0 399.9 398.7 3.2 0.0 120.00 0.0 120.00 102.2 120.00 102.3 I.. F450 01/17/10 05:29:53.378 401.0 399.9 398.8 3.4 0.0 120.00 0.0 120.00 102.2 120.00 102.3 I.. M449 01/17/10 05:29:53.395 400.8 399.9 398.9 3.2 0.0 120.00 0.0 120.00 102.2 120.00 102.3 I.. M448 01/17/10 05:29:53.412 400.9 400.0 398.7 3.2 0.0 120.00 0.0 120.00 102.2 120.00 102.3 I.. M447 01/17/10 05:29:53.428 400.9 399.9 398.8 3.3 0.0 120.00 0.0 120.00 102.2 120.00 102.3 I.. M446 01/17/10 05:29:53.445 400.9 399.9 398.8 3.2 0.0 120.00 0.0

=>>

Figure 6.7 Example Voltage Sag/Swell/Interruption (VSSI) Report (Meter Form 9)

The voltage sag/swell/interruption (VSSI) report in Figure 6.8 shows the format of the VSSI report headings when the meter is configured for delta-connected PTs (Meter Form 5). In this case, the Ph ABC column represents the Meter Word bits as shown on the right-hand side of Table 6.2. Note that the voltage column headings are now Vab, Vbc, and Vca to account for the phase-to-phase quantities (as compared to Figure 6.7).

=>SSI 295 300 <Enter>Processing.


FID=SEL-734-X345-V0-Z101101-D20100210 CID=BBF6

I nom. A B C G = 5 Amp N = 5 Amp Ph-A Ph-B Ph_C

Current(%I nom.) Vbase Volt Vbase Volts Vbase Volts Ph ST# Date Time Ia Ib Ic Ig In (Vsec) %Vbase (Vsec) %Vbase (Vsec) %Vbase ABC

300 01/17/10 05:30:01.557 400.9 399.9 398.8 3.2 0.0 120.00 102.2 120.00 102.6 120.00 0.0 ..I M299 01/17/10 05:30:01.574 401.0 399.9 398.7 3.3 0.0 120.00 102.3 120.00 102.6 120.00 0.0 ..I M298 01/17/10 05:30:01.590 400.8 399.9 398.8 3.3 0.0 120.00 102.2 120.00 102.5 120.00 0.0 ..I M297 01/17/10 05:30:01.607 400.8 399.9 398.8 3.3 0.0 120.00 102.2 120.00 102.6 120.00 0.0 ..I M296 01/17/10 05:30:01.624 401.0 399.9 398.6 3.3 0.0 120.00 102.3 120.00 102.6 120.00 0.0 ..I M295 01/17/10 05:30:01.640 400.8 399.9 398.8 3.3 0.0 120.00 102.3 120.00 102.6 120.00 0.0 ..I M=>

Figure 6.8 Example Voltage Sag/Swell/Interruption (VSSI) Report (Meter Form 5)

6.14


Power Quality and Event AnalysisFlicker Meter

VSSI RetrievalEnter SSI (without any numbers) to display all rows of the SSI summary. The meter displays the oldest row at the top of the report.

Enter SSI with a row number to display the specified number of rows. For example, the command SSI 17 displays the first (oldest) 17 rows of the SSI report.

Enter SSI with two row numbers to display the rows and all rows in between these. For example, the command SSI 10 33 displays rows 10 through 33 of the SSI report. When the first row number (10 in this example) is less than the second row number, the meter displays the oldest rows at the top of the report and the newest rows at the bottom of the report. When the first row number is larger than the second row number, the meter displays the newest rows at the top of the report and the oldest rows at the bottom.

Enter SSI with a date to display all SSI rows from the present to the date. Enter SSI with two dates to display all SSI rows in between the dates.

Table 6.7 shows examples of the SSI command.

VSSI Report Memory DetailsThe meter retains a minimum of 11,000 of the most recent VSSI entries in nonvolatile memory. If the VSSI recorder memory clears while an VSSI report is being displayed, the VSSI report will stop and display this message:

Command Aborted, Data overwrite occurred

VSSI Meter Word BitsUpon a voltage disturbance, the VSSI recorder asserts Meter Word Bits that offer a binary disturbance summary. Mapping these VSSI Meter Word Bits to the Sequential Events Recorder (SER) allows rapid analysis of a disturbance and its corresponding CBEMA/ITIC region. See Table 9.4 for a definition of each bit.

Flicker MeterLight flicker from incandescent bulbs caused by fluctuation of voltage magnitude can interfere with the human eye and brain in addition to sensitive electrical equipment. The SEL-734P calculates short- and long-term flicker values in accordance to IEC 61000-4-15 Flickermeter. The short-term flicker value, PST, is available in 10-minute intervals, and long-term flicker, PLT, is available in 2-hour intervals. The SEL-734P reports flicker data through the

Table 6.7 Example SSI Commands

SSI Command Description

SSI 17 Displays the last 17 rows of SSI Data.

SSI 17 20 Displays rows 17 through 20 of SSI Data.

SSI 20 17 Displays rows 20 through 17 of SSI Data.

SSI 11/1/2011 Displays SSI rows from the present to 11/1/2011.

SSI 11/1/2011 12/1/2011 Displays SSI rows from 11/1/2011 to 12/1/2011.

SSI 12/1/2011 11/1/2011 Displays SSI rows from 12/1/2011 to 11/1/2011.

6.15


Power Quality and Event AnalysisFlicker Meter

MET FL command, front-panel, display points, DNP, Modbus, Analog Outputs, ACSELERATOR QuickSet HMI, and the Load Profile (LDP) recorder. Since flicker data update once every 10 minutes and 2 hours, this information is easily retrieved from a SCADA master using the SEL, Modbus, or DNP3 protocols. In addition, the LDP recorder in the SEL-734P provides a very useful tool for trending, reporting, and graphing flicker data.

To trend flicker in the LDP recorder, apply the following settings:

➤ LDFUNC2: EOI

➤ LDLIST2: PLT_VA,PLT_VB,PLT_VC,PST_VA,PST_VB,PST_VC

➤ LDAR2: 10M

➤ LMDUR2: As desired

Figure 6.9 LDP Flicker Settings

The SEL-734P will now record short- and long-term flicker every 10 minutes. Retrieve the LDP2 recorder values using the ACSELERATOR QuickSet HMI or SCADA protocol to view the flicker trend. Any flicker value over one is likely to disturb the human eye and is a good threshold to consider corrective actions on the power system.

6.16


Power Quality and Event AnalysisHarmonic Triggers and Logs

Figure 6.10 Flicker Trend From LDP

Harmonic Triggers and LogsThe following describes different ways to configure the meter for harmonic triggering and logging.

Method 1 Configure the Harmonic Trigger Settings in the SEL-734 to a variable percentage of the fundamental current/voltage. These triggers will assert on either current or voltage harmonics.

Place these trigger values in the SEL-734 SER and EVE reports. The SEL-734 will record in the SER and trigger a waveform capture for every harmonic disturbance.

6.17



Method 2 Create analog harmonic triggers for each harmonic of interest, for example, odd-harmonic voltages.

Store an SER record when ER1 triggers.

Method 3 Log Harmonics in the LDP recorder and set the LDFUNC setting to MAX or AVG.

Methods to Reduce Analog Quantities

Use THD in place of discrete harmonic values.

6.18



Create an average harmonic voltage value for each discrete harmonic order using SELOGIC Math Variables.

Next, plot these new SELOGIC Math Variables in LDP, or create an EVEnt report trigger.


Section 7Time-Synchronized Measurements

OverviewThe SEL-734 Meter records power system events with very high accuracy when it is provided with high-accuracy clock input signals, such as from a GPS receiver. Meters placed at key substations can give you information on power system operating conditions in real time or accumulate records when events occur.

Based on the high-accuracy time input, the meter calculates synchronized phasors for line currents and voltages (for each phase and for positive-sequence). You can then perform detailed analysis and calculate load flow from the synchrophasors.

This section presents details on these measurements as well as suggestions for further application areas, such as the following:

➤ Meter Configuration for High-Accuracy Timekeeping

➤ Synchrophasor Measurements

➤ Power Flow Analysis

➤ State Estimation Verification

Meter Configuration for High-Accuracy TimekeepingIRIG-B You can connect time signals from many sources that produce the

demodulated IRIG-B (Inter-Range Instrumentation Group-B) time code format (e.g., SEL-2032, GPS receiver). The IRIG-B signal includes codes for time-of-day and day-of-year time stamping. The signal does not include a code to identify the year.

To verify that the SEL-734 calendar is set to the proper year, issue the DATE command to view or change the date. The meter stores the year in nonvolatile memory and will maintain the proper year even if meter power cycles off and on. The meter also maintains the time, month, and day in nonvolatile memory while the meter power is off.

The IRIG-B serial data format consists of a one-second frame containing 100 pulses divided into fields. The meter decodes the second, minute, hour, and day fields and sets the internal time clock upon detecting valid time data.

Maximum jitter of the input IRIG-B signal must be less than ±1 μs.

Automatic Time-Source Selection

The SEL-734 automatically switches time-source inputs from internal to IRIG-B if a valid IRIG signal is connected.

If the IRIG-B time source is unavailable or is unreliable, the meter switches to the internal source. The meter automatically switches to a higher priority time

7.2


Time-Synchronized MeasurementsMeter Configuration for High-Accuracy Timekeeping

source (IRIG-B) when the meter measures an acceptable time source stability and reliability. Time source selection can be determined by using the STATUS command and observing the time source.

When an IRIG-B time source is present, the meter ignores the Daylight-Saving Time settings.

Connecting High-Accuracy Time-Keeping

The procedure in the following steps assumes that you have a modern high-accuracy GPS receiver with a demodulated IRIG-B signal. This example assumes that you have successfully established communication with the meter. In addition, you must be familiar with meter access levels and passwords.

Step 1. Prepare to control the meter at Access Level 2.

a. Type ACC <Enter> at a communications terminal.

b. Type the Access Level 1 password and press <Enter>. You will see the => prompt.

c. Type the 2AC <Enter> command, and then type the correct password to go to Access Level 2. You will see the =>> prompt.

Step 2. Connect the cable.

Step 3. Attach the IRIG-B signal from the GPS receiver IRIG-B output to the IRIG-B connector on the meter.

Step 4. Confirm automatic detection and changeover to timing mode by issuing the STA command.

Step 5. Confirm that Time Source: ext is the response you receive.

Figure 7.1 High-Accuracy Timekeeping Connections

GPS Receiver

IRIG-B COMM

to Data Server

SEL-734

7.3


Time-Synchronized MeasurementsSynchrophasor Measurements

Synchrophasor MeasurementsIntroduction Synchronized phasor measurement provides power system data referenced to

the same instant in time from multiple SEL-734 meters at different locations on a power system. This feature reduces time for system state estimation, which results in improved system optimization and increased line loading with fewer safety margin requirements.

This subsection details the retrieval of synchrophasor (synchronized phasor measurement) data from the SEL-734. You can access data as fast as 20 samples per second to monitor the power system in real time.

System RequirementsBasic Connections

Each SEL-734 must be connected to a timing source, such as a global positioning system (GPS) receiver, that is accurate to within ±0.50 μs of Coordinated Universal Time (UTC). The clock source must be able to provide a demodulated IRIG-B signal. Use the 2-pin phoenix connector labeled IRIG-B to connect the SEL-734 to this source.

SpecificationsThe SEL-734 Meter Word contains a “Timing Source OK” element (TSOK) that asserts when the IRIG-B signal has been present for a sufficient duration to allow the SEL-734 to obtain proper internal time lock. A second Meter Word, PMDOK, asserts when TSOK has asserted and the synchronized phasor algorithm is at the specified accuracy. When PMDOK asserts, the SEL-734 provides synchronized measurement accuracy with level 0 of IEEE C37.118-2005. Depending on the application, loss of the time source signal, with corresponding PMDOK deassertion, can cause the accuracy of the synchronized data to be outside specifications or the meter to respond with an abort message. PMDOK also deasserts if the meter is disabled.

SettingsYou must enable synchronized phasor measurements by setting EPMU := Y before the SEL-734 reports synchrophasor data (see SET G Command on page SET.6). See Table 7.1 for a list of all required synchrophasor settings.

When EPMU := Y, the meter prompts for the synchrophasor precision time source type through the TSTYPE setting. The TSTYPE setting accepts either an IRIG or IEEE time source input. When TSTYPE = IRIG, the SEL-734 expects local time from the IRIG time source. When TSTYPE = IEEE, the SEL-734 expects the IRIG message to contain a UTC offset, encoded according to the IEEE C37.118-2005 standard.

The port settings for the SEL-734 contain PMDATA and PMADDR settings specific to the synchrophasor application. The PMDATA setting provides you the choice of analog quantities that the SEL-734 transmits in the synchrophasor message (see Table 7.1).

The PMADDR setting assigns a unique address to synchrophasor data that identifies each SEL-734.

7.4



Meter Forms 5 and 9The SEL-734 is factory configured according to the voltage connection ordering option in Form 5 or Form 9. Form 5 corresponds to delta voltage connection, and Form 9 corresponds to wye voltage connection. The SEL-734 reports phase-to-neutral voltage synchrophasors regardless of the voltage connection option. Form 5 and Form 9 synchrophasor reports indicate identical values only during balanced voltage conditions.

MET PM CommandThe MET PM serial port ASCII command displays synchrophasor measurements from the SEL-734. See MET PM (Synchrophasors) on page 10.23 for detailed information on the MET PM command.

There are multiple ways to use the MET PM command:

➤ As a test tool to verify connections, phase rotation, and scaling.

➤ As an analytical tool to capture synchrophasor data at an exact time for comparison with similar data other phasor measurement units have captured.

➤ As a method for periodically gathering synchrophasor data through a communications processor.

SEL Unsolicited Fast Message ProtocolApplication

Electric power system dispatch and control functions must work with the most accurate and up-to-date information possible to maximize scarce system resources. High loading levels across a transmission system reduce the ability of the system to recover from faults and loss of generation. By knowing the exact load angle between points on a power system, operators can make control decisions that maintain stability without unnecessarily restricting power transfers. Instead of using average voltage magnitudes and power flows with a state estimation algorithm, operators can use the instantaneous voltage angle across a system as a basis for control decisions. Eliminating the margin for error inherent in a state estimation system allows increased load flows while maintaining stability.

SetupUnsolicited Fast Messaging is an open SEL binary communications protocol. To decipher and use the data in the Fast Messages, you must parse the data with a software program, such as Microsoft® Excel with Visual Basic® for Applications or LabView®, that is capable of handling communications and 32-bit floating-point number conversion. Table 7.3 provides a complete description of the Fast Message packet.

Table 7.1 Required Synchrophasor Settings

Global Settings

EPMU := Y

TSTYPE := IRIG or IEEE

Port Settings

PMDATA := V1, V, or A

PMADDR := User defined

7.5



The application of the SEL-734 using unsolicited Fast Messaging requires consideration of a few issues. First, you must decide what data are required for the application. Second, you must decide how often messages must be transmitted to satisfy the application requirements. Last, you must evaluate the communications channels that will transfer the Unsolicited Fast Messages from the meter to the PC or data concentrator. You must verify that the communications medium can handle the quantity of data and the frequency of the messages. Once these questions are answered, you can adjust the serial port setting to the meter and send the enable message to start receiving synchrophasor data.

Determine the Data RequiredThe SEL-734 can provide either positive-sequence voltage, three-phase and positive-sequence voltages, or three phases of voltage, three phases of current, and positive-sequence voltage and current. Use the PMDATA port setting to select the data for synchrophasor Fast Message transmission. See Table 7.2 for details.

In addition to the synchrophasor data, sixteen digital values can be sent in the Fast Message. The least significant bit contains PMDOK. Next is TSOK. The next 14 bits are SV03 through SV16.

The frequency data in the Fast Message is based on the Synchrophasor phase angle when the frequency is in range Fnom ± 5 Hz. The total frequency range that can be reported is 35 Hz to 75 Hz.

Assign Identification Addresses to Each MeterThe power system can benefit the most from the application of synchrophasors when data are retrieved from multiple locations simultaneously. You must be able to discern which meter is sending which data. The PMADDR port setting provides a four-byte identification tag in each message packet. Use the PMADDR setting to identify synchrophasor data from specific locations on the transmission system.

Table 7.2 PMDATA Setting for Synchrophasor Fast Message Data Selection (Form 9 Meter)

PMDATA Setting Data Size of Packet in Bytes

V1 V1 40

V VA, VB, VC, V1 64

A VA, VB, VC, V1, IA, IB, IC, I1 96

Table 7.3 SEL Fast Message Protocol Format (Sheet 1 of 2)

Field Description Hex Data

Header Synchrophasor Fast Message A546

Frame Size 40 bytes for PMDATA = V1a 28

Routing Must be 0000000000 for this application 0000000000

Status Byte Must be 00 for this application 00

Function Code 20h Code for unsolicited write messages 20

Sequence C0 for single frame message C0

Maximum frame size 255 bytes

C0

Response Number XX = 00, 01, 02, 03 00

7.6



Decide the Rate at Which You Want to Receive Fast MessagesThe SEL-734 can transmit Unsolicited Fast Messages at the rate of 1, 2, 4, 5, 10, or 20 times per second. For Fnom = 50, the maximum rate is 10 times per second. The packet sent to enable unsolicited synchrophasor data contains a byte that defines the rate at which the SEL-734 will transmit synchrophasor data. Use Table 7.4 to determine the correct value to insert in the enable message.

Evaluate the Communications Channel BandwidthOnce you know the frequency and size of the messages, use Equation 7.1 to determine the rate at which the Fast Messages can be sent:

Equation 7.1

PM Data Address Address of Synchrophasor

Measurement Data (PMADDR setting)

00000000

Register Countb Data size in registers (1 Register = 2 Bytes) XXXX

Sample Number 0-based index into SOC of this packet XXXX

SOC Second of century XXXXXXXX

Frequency IEEE 32-bit floating pointc XXXXXXXX

Phasor Mag. V1 Magnitude (IEEE 32-bit floating point) XXXXXXXX

Phasor Angle V1 Angle ± 180° (IEEE 32-bit floating point) XXXXXXXX

Digital Data SV16–SV03

TSOK (Time Synchronization OK)

PMDOK (Phasor Measurement Data OK)

XXXX

Check Word 2-byte CRC-16 check code for message XXXX

a When PMDATA=V1, size is 28h. When PMDATA=V, size is 40h. When PMDATA=A, size is 60h.b Register Count V1 = 0009h, V = 0016h, A = 0026h.c From ANSI/IEEE Std. 754–1985, The IEEE Standard for Binary Floating-Point Arithmetic.

Table 7.3 SEL Fast Message Protocol Format (Sheet 2 of 2)


Table 7.4 Unsolicited Write Message Transmission Rates

Number of Packets Per Second

Frequency of Packets in Milliseconds

Data Transmission Rate (nn–hexadecimal)

20 50 00h

20 50 05h

10 100 0Ah

5 200 16h

4 250 19h

2 500 32h

1 1000 64h

where:nn = message size (bytes)L = length of message byte (1 start bit, 8 data bits, 2 stop bits,

1 parity = 12)f = frequency of messages

1.2 = factor to account for system delays

bps 1.2(nn L f )• • =

7.7



For example, given that PMDATA = A, nn = 96 (60h), L = 12 (worst case), and the frequency of messages is 5 per second, the required baud rate would be at least 1.2 • (96 • 2 • 5) = 6912 bits per second. Therefore, the communications channel speed could be no less than 9600 baud.

Table 7.5 is a partial list of various combinations. If the application does not require updates more than once or twice a second, then bandwidth should not be an issue. If the communications system is in place, and the baud rate is below 38400 baud, then either the message frequency or analog values included in the packet will need to be adjusted.

Starting and Stopping Synchrophasor Fast MessagesIt is important to note that all synchrophasor messages, including the enable and disable messages, must be transmitted and received through use of a binary transmission method. Standard terminal emulation software will decipher the hex data as ASCII, and the meter will not respond as expected.

Enable Synchrophasor Fast MessagingAfter evaluating what data will be required, how often the data will be required, verifying that the communications channels will transfer the data adequately, and changing the appropriate settings, you are ready to construct the enable message. Table 7.6 shows the content and format required to enable the unsolicited synchrophasor binary messages.

Once the enable message is sent, the device will respond either with an acknowledge message followed by streaming synchrophasor data, or just streaming synchrophasor data, depending on the value of the YY status byte shown in Table 7.6. Note that the device only sends synchrophasor data out the port that receives the enable message, and the PMDATA and PMADDR settings are specific to each port.

Table 7.5 Minimum Bandwidth Requirements

PMDATA SettingTransmission Rate

(messages per second) Minimum Allowable

Baud Rate

V1 20 9600

V1 10 4800

V1 5 2400

V 20 19200

V 10 9600

V 5 4800

A 20 38400

A 10 19200

A 5 9600

A 4 4800

Table 7.6 Unsolicited Fast Message Enable Packet (Sheet 1 of 2)



Frame Size 18 bytes 12


Status Byte YY = 00 acknowledge is not requested

YY = 01 acknowledge is requested

YY

NOTE: The initial IRIG-B time synchronization can take up to a minute to occur.

7.8


Time-Synchronized MeasurementsPower Flow Analysis

Disable Synchrophasor Fast MessagingA binary disable message, similar to the enable message, must be sent to the transmitting port to stop the synchrophasor messages. Table 7.7 describes the packet for disabling the unsolicited synchrophasor Fast Messages. Once the message is sent, the meter will revert to a standard ASCII terminal port, and normal meter communications may resume.

Power Flow AnalysisUse the meter to develop instantaneous power flow data. Obtain the voltage and current phasors from different power system buses at the same instant and use these measurements to determine power flow at that moment in time.

Use the synchronized phasor measurement capabilities of the meter to collect synchronized voltage and current data. Use this information to confirm your power flow models.

Figure 7.2 shows how power flow analysis is accomplished using synchronized phasors. Four meters are installed in the power system. Substations S and R provide generation for the load at Substation T.

Function Code 01h Enable unsolicited write messages 01

Sequence C0 for single frame message.Maximum frame size 255 bytes

C0

Response Number XX = 00, 01, 02, 03 XX

Application 20h Synchrophasor 20

Reserved 00

Reserved 00

Message Rate Message transmission rate nn


Table 7.6 Unsolicited Fast Message Enable Packet (Sheet 2 of 2)


Table 7.7 Unsolicited Fast Message Disable Packet



Frame Size 16 bytes 10


Status Byte YY = 00 acknowledge is not requested

YY = 01 acknowledge is requested

YY

Function Code 02h Disable unsolicited write messages 02

Sequence C0 for single frame message;maximum frame size 255 bytes

C0

Response Number XX = 00, 01, 02, 03 XX

Application 20h Synchrophasor 20

Reserved 00


7.9



Figure 7.2 500 kV Three Bus Power System

Table 7.8 lists the voltages and currents measured by the four meters at one particular time.

Use Equation 7.2 to calculate the generation supplied from Substation S and Substation R, plus the load at Substation T shown in Figure 7.3.

Table 7.8 Meter Voltage and Current Measurement

Voltage Current

Meter at Substation S

VAS 288.675 kV ∠0 IAS 238.995 A ∠41.9

VBS 288.675 kV ∠240 IBS 238.995 A ∠78.1

VCS 288.675 kV ∠120 ICS 238.995 A ∠161.9

Meter at Substation R

VAR 303.109 kV ∠0.2 IAR 234.036 A ∠44.2

VBR 303.109 kV ∠239.8 IBR 234.036 A ∠195.8

VCR 303.109 kV ∠119.8 ICR 234.036 A ∠75.8

Meter at Substation T Looking Towards Substation S

VAT–S 295.603 kV ∠1.6 IAT–S 238.995 A ∠138.1

VBT–S 295.603 kV ∠238.4 IBT–S 238.995 A ∠101.9

VCT–S 295.603 kV ∠118.4 ICT–S 238.995 A ∠18.1

Meter at Substation T Looking Towards Substation R

VAT–R 295.603 kV ∠1.6 IAT–R 234.036 A ∠135.8

VBT–R 295.603 kV ∠238.4 IBT–R 234.036 A ∠15.8

VCT–R 295.603 kV ∠118.4 ICT–R 234.036 A ∠104.2

S T

SEL-734

GPS Rx

SEL-734

GPS Rx

SEL-734

GPS Rx

R

SEL-734

GPS Rx

7.10



Equation 7.2

The complex power generation supplied by Substation S is:

Equation 7.3

The complex power generation supplied by Substation R is:

Equation 7.4

The load at Substation T supplied by Substation S is:

Equation 7.5

The load at Substation T supplied by Substation R is:

Equation 7.6

The total load at Substation T is:

Equation 7.7

Figure 7.3 Power Flow Solution

Use the power flow solution to verify the instantaneous positive-sequence impedances of your system transmission lines.

where:S3ø = Three-phase complex power (MVA)P3ø = Three-phase real power (MW)Q3ø = Three-phase imaginary power (MVAR)Vpp = Phase-to-phase voltageVp = Phase-to-neutral voltageI*

L = Complex conjugate of the line current

S3ø P3ø jQ3ø +=

3 Vpp I*

L• • =

3 Vp I*

L• • =

SS 3 288.675 kV 0°∠• ( ) 238.995 A 41.9– °∠( )• =

154.1 MW – j138.2 MVAR=

SR 3 303.109 kV 0.2– °∠• ( ) 234.036 A 44.2°∠( )• =

152.6 MW + j148.3 MVAR=

ST S– 3 295.603 kV 1.6– °∠• ( ) 238.995 A 135.8°∠( )• =

153.7 MW + j145.9 MVAR=

ST R– 3 295.603 kV 1.6– °∠• ( ) 234.036 A 135.8– °∠( )• =

152.8 MW – j140.5 MVAR–=

ST ST S– ST R–+=

306.5 MW– j5.4 MVAR+=

S T

R

P = 154.1 MW

P = 306.5 MW

P = 153.7 MW

P = 153.1 MW P = 152.8 MW

Q = 138.2 MVAR Q = 145.9 MVAR

Q = 147.8 MVAR Q = 140.5 MVAR

Q = 5.4 MVAR

Line LossP = 0.4 MWQ = 7.7 MVAR

Line LossP = 0.3 MWQ = 7.3 MVAR

7.11


Time-Synchronized MeasurementsState Estimation Verification

State Estimation VerificationElectric utility control centers have used state estimation to monitor the state of the power system for the past 20 years. The state estimator calculates the state of the power system through use of measurements such as complex power, voltage magnitudes, and current magnitudes received from different substations.

State estimation uses an iterative, nonlinear estimation technique. The state of the power system is the set of all positive-sequence voltage phasors in the network. Typically, several seconds or minutes elapse from the time of the first measurement to the time of the first estimation. Therefore, state estimation is a steady-state representation of the power system.

Consider using precise simultaneous positive-sequence voltage measurements from the power system to verify your state estimation model. Take time-synchronized, high-resolution positive-sequence voltage measurements at all substations. Send the Meter Fast Messages to a central database to determine the power system state.



Section 8Logic

OverviewThis section explains the settings and operation of the logic input/output of the SEL-734 Meter, including the following:

➤ Optoisolated Inputs

➤ Remote Control Switches

➤ Latch Control Switches

➤ Local Control Bit

➤ SELOGIC® Control Equation Variables/Timers

➤ SELOGIC Math Variables

➤ Analog Control Values

➤ SELOGIC Counter Variables

➤ KYZ Outputs

➤ Output Contacts

➤ Analog Outputs

➤ Rotating Displays

Table 8.1 describes all of the logic input/output of SEL-734.

This section explains the operation of these inputs.

Table 8.1 SEL-734 Logic Inputs and Outputs (Sheet 1 of 2)

Description Setting Model Reference

Optoisolated inputs IN101–IN102 0734ES2-XX0734ES2-6X

IN401–IN404 0734ES2-6X

Remote control switches Remote bits RB01–RB16

Latch control switches Latch bits LT01–LT32

SELOGIC control equations variables/timers

SV01/SV01T–SV32/SV32T

SELOGIC math variables MV01–MV32

Analog control values ACV01–ACV32

SELOGIC counter variables SC01–SC32

Output contacts OUT101–OUT103 0734ES2-XX0734ES2-6X

OUT401–OUT404 0734ES2-6X

8.2


LogicOptoisolated Inputs

Optoisolated InputsFigure 8.1 and Figure 8.2 show the resultant Meter Word bits (e.g., Meter Word bits IN101 through IN102) that follow corresponding optoisolated inputs (e.g., optoisolated inputs IN101 through IN102) for the different SEL-734 models.

The figures show examples of energized and de-energized optoisolated inputs and corresponding Meter Word bit states. To assert an input, apply rated control voltage to the appropriate terminal pair (see Figure 1.3 and Figure 2.9).

Figure 8.1 is used for the following discussion/examples. The optoisolated inputs in Figure 8.2 operate similarly.

Figure 8.1 Example Operation of Optoisolated Inputs IN101 Through IN102 (Models 0734ES2-XX and 0734ES2-6X)

Analog Outputs AO401–AO404 0734ES2-8x

Rotating default displays Display points DP01–DP32

Table 8.1 SEL-734 Logic Inputs and Outputs (Sheet 2 of 2)

Description Setting Model Reference

open

closed

ExampleSwitch States

OptoisolatedInput States

OptoisolatedInputs

Built-InDebounce

Timers

MeterWordBits

MeterWord Bits

States

IN101 de-energized IN101 logical 0

energizedIN102 IN102 logical 1

(+)

(-)

IN101D

IN101D

IN102D

IN102D

8.3


LogicOptoisolated Inputs

Figure 8.2 Example Operation of Optoisolated Inputs IN401 Through IN404, Extra I/O Board (Model 0734ES2-6X)

Input Debounce Timers

Each input has settable pickup/dropout timers (IN101D and IN102D) for input energization/de-energization debounce. Notice in Figure 8.1 that a given time setting (e.g., IN101D = 25 ms) is applied to both the pickup and dropout time for the corresponding input (see SET G Command on page SET.6 of the SEL-734 Settings Sheets for valid debounce timer settings).

Time settings IN101D and IN102D are settable from 0 to 25 ms or ac setting. The meter takes the entered time setting and internally runs the timer at 1 ms. For example, if setting IN102D = 14, internally the timer runs at 1 ms; the delay is 14 ms.

The ac setting allows the input to sense ac control signals. The input has a maximum pickup time of 25 ms and a maximum dropout time of 25 ms. The ac setting qualifies the input by not asserting until two successive 1 ms samples are higher than the optoisolated input voltage threshold and not deasserting until 12 successive 1-ms samples are lower than the optoisolated input voltage threshold.

For dc applications, the input pickup/dropout debounce timers are set in 1 ms increments. For example, in the factory default settings, all the optoisolated input pickup/dropout debounce timers are set at 5 ms (e.g., IN101D = 5). See SHO Command (Show/View Settings) on page 10.24 for a list of the factory default settings.

The meter processing interval is 25 ms, so Meter Word bits IN101 through IN102 are updated every 25 ms. The optoisolated input status may have made it through the pickup/dropout debounce timer (for settings less than 25 ms) because these timers run each 25 ms, but Meter Word bits IN101 through IN102 are updated every 25 ms.

If more than 25 ms of debounce is needed, run Meter Word bit INn (n = 1 through 2) through a SELOGIC control equation variable timer and use the output of the timer for input functions (see Figure 8.10).

ExampleSwitch States

OptoisolatedInput States

OptoisolatedInputs

Built-InDebounce

Timers

MeterWordBits

MeterWord Bits

States

open

closed



(+)

IN401D

IN401D

IN402D

IN402D

open

closed



(-)

IN403D

IN403D

IN404D

IN404D

8.4


LogicRemote Control Switches

Input Functions There are no optoisolated input settings such as:

IN101 = OUT101

IN102 = ER1

Optoisolated inputs IN101 and IN102 control Meter Word bits IN101 and IN102 that are used in SELOGIC control equations.

Remote Control SwitchesThe outputs of the remote control switches in Figure 8.3 are Meter Word bits RBn (n = 01 to 16), called remote bits. Use these remote bits in SELOGIC control equations (see CON Command (Control Remote Bit) on page 10.29).

Figure 8.3 Remote Control Switches Drive Remote Bits RB01 Through RB16

Any given remote control switch can be put in one of the following three positions:

Remote Bit States Not Retained When Power Is Lost

The states of the remote bits (Meter Word bits RB01 through RB16) are not retained if meter power is cycled. The remote control switches always come back in the OFF position (corresponding remote bit is deasserted to logical 0) when power is restored to the meter.

Remote Bit States Retained When Settings Changed

The state of each remote bit (Meter Word bits RB01 through RB16) is retained if meter settings are changed.

If a remote control switch is in the ON position (corresponding remote bit is asserted to logical 1) before a setting change, it comes back in the ON position (corresponding remote bit is still asserted to logical 1) after the change. If a remote control switch is in the OFF position (corresponding remote bit is deasserted to logical 0) before a settings change, it comes back in the OFF position (corresponding remote bit is still deasserted to logical 0) after the change.

ON (logical 1)OFF (logical 0)MOMENTARY (logical 1 for one processing interval – 25 ms)

Logical 1OFF position(maintained

logical 0 position)

ON position(maintained logical 1 position)

MOMENTARY position(logical 1 for one processing interval)

RBn (n = 01 through 16)

MeterWordBit

The switch representation in this figure is derived from the standard:

Graphic Symbols for Electrical and Electronics DiagramsIEEE Standard 315-1975, CSA Z99-1975, ANSI Y32.2-1975

4.11 Combination Locking and Nonlocking Switch, Item 4.11.1

8.5


LogicLatch Bits

Details on the Remote Control Switch MOMENTARY Position

This subsection describes how to operate remote bit RB03 as a momentary switch. You can make RB01–RB16, operate in the same way.

The CON 3 command and PRB 3 subcommand place the remote control switch 3 into the MOMENTARY position for one processing interval, regardless of its initial state. Remote control switch 3 is then placed in the OFF position.

If RB03 is initially at logical 0, pulsing it with the CON 3 command and PRB 3 subcommand will change RB03 to logical 1 for one processing interval, and then return it to logical 0. In this situation, the R_TRIG RB03 (rising edge operator) will also assert for one processing interval, followed by the F_TRIG RB03 (falling edge operator) one processing interval later.

If RB03 is initially at logical 1 instead, pulsing it with the CON 3 command and PRB 3 subcommand will change RB03 to a logical 0. In this situation, the R_TRIG RB03 (rising edge operator) will not assert, but the F_TRIG RB03 (falling edge operator) will assert for one processing interval.

Latch BitsLatch control switches (Latch Bits are the outputs of these switches) replace traditional latching relays. Traditional latching relays maintain their output contact state. The SEL-734 latch control switches retain their state even when power to the meter is lost. If the latch control switch is set to a programmable output contact and power to the meter is lost, the state of the latch control switch is stored in nonvolatile memory, but the output contact will go to its de-energized state. When power to the meter is restored, the programmable output contact will go back to the state of the latch control switch after meter initialization.

Traditional latching relay output contact states are changed by pulsing the latching relay inputs (see Figure 8.4). Pulse the set input to close (set) the latching relay output contact. Pulse the reset input to open (reset) the latching relay output contact. Often the external contacts wired to the latching relay inputs are from remote control equipment (e.g., SCADA, RTU).

Figure 8.4 Traditional Latching Relay

Thirty-two latch control switches in the SEL-734 provide latching relay functionality.

SetInput

ResetInput

OutputContact

TraditionalLatching

Relay

(+)

(–)

8.6


LogicLatch Bits

Figure 8.5 Latch Control Switches Drive Latch Bits LT01 Through LT32

The output of the latch control switch in Figure 8.5 is a Meter Word bit LTn (n = 01 through 32), called a latch bit. The latch control switch logic in Figure 8.5 repeats for each latch bit LT01 through LT32. Use these latch bits in SELOGIC control equations (see Latch Bits Set/Reset Equations (see Figure 8.5) on page SET.5 of the SEL-734 Settings Sheets for latch bit settings).

These latch control switches each have the following SELOGIC control equation settings:

SETn (set latch bit LTn to logical 1)

RSTn (reset latch bit LTn to logical 0)

If setting SETn asserts to logical 1, latch bit LTn asserts to logical 1. If setting RSTn asserts to logical 1, latch bit LTn deasserts to logical 0. If both settings SETn and RSTn assert to logical 1, setting RSTn has priority and latch bit LTn deasserts to logical 0.

Latch Bits: Application IdeasLatch control switches can be used for such applications as:

➤ Battery charger health status alarm latching

➤ Predictive demand alarm enable/disable

Latch control switches can be applied to almost any control scheme. The following is an example of using a latch control switch to add the battery charger health status to the meter ALARM contact (output contact OUT103 by default).

Example: Adding Battery Charger Health Status to ALARM ContactUse a latch control switch to add battery charger health status alarm latching to the SEL-734. In this example, a SCADA contact is connected to optoisolated input IN102 as shown in Figure 8.6. Use a Remote Bit instead of an input if your application warrants it.

If the ALARM output contact is enabled and the battery charger health status contact is pulsed, the ALARM output contact is then disabled. If the battery charger health status contact is pulsed again, the ALARM output contact is enabled again. Each pulse of the battery charger health status contact changes the state of the ALARM output contact. The control operates in a cyclic manner. The battery charger health status contact is not maintained, just pulsed to enable/disable the ALARM output contact.

LTnSETn

RSTn

(Set)

(Reset)(n = 01 through 16)

Meter WordBits

SELOGICSetting

8.7


LogicLatch Bits

Figure 8.6 Battery Charger Health Status Contact Pulses Input IN102 to Enable/Disable ALARM Output Contact

This ALARM output contact logic is implemented in the following SELOGIC control equation settings and is displayed in Figure 8.7. Note that the figure includes an extra timer that is not included in the settings. This timer will be used in the next example. Figure 8.8 shows the timing for this example.

SET01 := (R_TRIG IN102) AND (NOT LT01)

RST01 := (R_TRIG IN102) AND LT01

OUT103 := NOT (SALARM OR HALARM) OR (NOT LT01)

Figure 8.7 Single Input to Control ALARM

Figure 8.8 Latch Control Switch Operation Time Line

(+)

Battery ChargerHealth Status

Contact

(—)

SEL Input IN102Enable/Disable ALARMOutput Contact

LT01NOT LT01

IN102

(Set)

(Reset)

SET01

RST01

SELOGICSetting

SELOGICSetting SELOGIC

Setting

MeterWordBit

MeterWordBit

Meter WordBit

MeterWordBits

SV06PU

SV06D0

SV06T

R_TRIG

Latch Bit

SV06

SALARM

HALARM

OUT103

RST01

R_TRIG IN102

IN102

SET01

LT01

RisingEdge

OneProcessingInterval

RisingEdge

RisingEdge

RisingEdge

8.8


LogicLatch Bits

A variation of the previous example adds more security by adding a timer with equal pickup/dropout times as shown in Figure 8.7. Suppose that SV06PU and SV06DO are both set to 5 seconds. Then the SV06T timer keeps the state of latch bit LT01 from being able to be changed at a rate faster than once every 5 seconds. Figure 8.9 shows the timing for this example.

SV06 := LT01

SET01 := (R_TRIG IN102) AND (NOT SV06T)

RST01 := (R_TRIG IN102) AND SV06T

OUT103 := NOT (SALARM OR HALARM) OR (NOT LT01)

Note in Figure 8.7 that the latch control switch output (latch bit LT01) uses feedback for SELOGIC control equation settings SET01 and RST01. The feedback of latch bit LT01 determines whether input IN102 operates the SET01 or RST01 input. If latch bit LT01 := logical 0, input IN102 operates SET01 (set latch bit LT01). If latch bit LT01 := logical 1, input IN102 operates RST01 (reset latch bit LT01).

Figure 8.9 Latch Control Switch (With Time-Delay Feedback) Operation Time Line

Latch Bits: Nonvolatile StatePower Loss

The states of the latch bits (LT01–LT32) are retained if power to the meter is lost and then restored. If a latch bit is asserted (e.g., LT02 := logical 1) when power is lost, it is asserted (LT02 := logical 1) when power is restored. If a latch bit is deasserted (e.g., LT03 := logical 0) when power is lost, it is deasserted (LT03 := logical 0) when power is restored. This feature makes the latch bit feature behave the same as traditional latching relays. In a traditional installation, if power is lost to the panel, the latching relay output contact position remains unchanged.

Settings ChangeIf individual settings are changed, the states of the latch bits are retained, much like in the preceding Power Loss explanation.

RST01

R_TRIG IN102

IN102

SET01

RisingEdge

OneProcessingInterval

SV06DOSV06PU

Pulse 1 Pulse 2 Pulse 3 Pulse 4

RisingEdge

RisingEdge

No Effect

No Effect

RisingEdge

SV06 := LT01

SV06T

NOTE: If a latch bit is set to a programmable output contact, such as OUT103 := LT02, and power to the meter is lost, the state of the latch bit is stored in nonvolatile memory but the output contact will go to its de-energized state. When power to the meter is restored, the programmable output contact will go back to the state of the latch bit after meter initialization.

8.9


LogicSELOGIC Control Equation Variables/Timers

If the individual settings change causes a change in SELOGIC control equation settings SETn or RSTn (n = 01 through 32), the retained states of the latch bits can be changed, subject to the newly enabled settings SETn or RSTn.

Make Latch Control Switch Settings With CareThe latch bit states are stored in nonvolatile memory so they can be retained during power loss or settings change. The nonvolatile memory is rated for a finite number of writes for all cumulative latch bit state changes. Exceeding the limit can result in a NONVOL self-test failure. An average of 70 cumulative latch bit state changes per day can occur for a 25-year meter service life.

This requires that SELOGIC control equation settings SETn and RSTn for any given latch bit LTn (n = 01 through 32) be set with care. Settings SETn and RSTn cannot result in continuous cyclical operation of latch bit LTn. Use timers to qualify conditions set in settings SETn and RSTn. If any optoisolated inputs are used in settings SETn and RSTn, the inputs have their own debounce timer that can help in providing the necessary time qualification.

In the preceding example application of adding a battery charger health status to the ALARM contact (Figure 8.6), the battery charger health status contact cannot be asserted/deasserted continuously, a situation that would cause latch bit LT01 to change state continuously. Note that the rising edge operators in the SET01 and RST01 settings keep latch bit LT01 from cyclical operation for any single assertion of the battery charger health status contact.

Local Control Bit The SEL-734 provides local control using the front-panel RESET pushbutton and the Meter Word bit, RESET (see Meter Word Bits (Used in SELogic Control Equations) on page 9.2). Any time the RESET pushbutton is pressed, the RESET Meter Word changes state from logical 0 to logical 1 (asserts), and changes back to logical 0 (deasserts) when the button is released. Use the RESET bit as you would any other Meter Word bit in SELOGIC control equations to perform a specific function when the RESET button is pressed. For example:

OUT101 = RESET

When the RESET front-panel pushbutton is pressed, the Meter Word bit RESET asserts, causing OUT101 to close. Releasing the pushbutton deasserts the RESET bit, causing the output to open.

SELOGIC Control Equation Variables/TimersThe SEL-734 has thirty-two (32) SELOGIC control equation variables/timers. Each SELOGIC control equation variable/timer has a SELOGIC control equation setting input and variable/timer outputs as shown in Figure 8.10.

Timers SV01T through SV32T in Figure 8.10 have a setting range of a little over four minutes (see SELogic Variables Timer Settings on page SET.5 of the SEL-734 Settings Sheets):

0.000–1000000.000 seconds in 25-ms increments

These timer setting ranges apply to both pickup and dropout times (SVnPU and SVnDO, n = 01 through 32).

8.10


LogicSELOGIC Control Equation Variables/Timers

Figure 8.10 SELOGIC Control Equation Variables/Timers SV01/SV01T Through SV32/SV32T

SELOGIC Control Equation Operators

Use the analog comparators to create a Boolean result from an analog value (see Appendix H: Analog Quantities), and Boolean operators to combine values with a resulting Boolean value. Edge trigger operators provide a pulse output. Combine the operators and operands to form statements that evaluate complex logic. Table 8.2 contains a summary of operators available in the SEL-734.

Operator PrecedenceWhen you combine several operators and operands within a single expression, the SEL-734 evaluates the operators from left to right, starting with the highest precedence operators and working down to the lowest precedence. This means that if you write an equation with three AND operators, for example SV01 AND SV02 AND SV03, each AND will be evaluated from the left to the right. If you substitute NOT SV04 for SV03 to make SV01 AND SV02 AND NOT SV04, the meter evaluates the NOT operation of SV04 first and uses the result in subsequent evaluation of the expression. Operator precedence is shown in Table 8.2.

Timers Reset When Power Is Lost or Settings Are Changed

If power is lost to the meter or if settings change, the SELOGIC control equation variables/timers reset. Meter Word bits SVn and SVnT (n = 01 through 32) reset to logical 0 after power restoration or a settings change.

Figure 8.11 shows an effective seal-in logic circuit, created by use of Meter Word bit SV07 (SELOGIC control equation variable SV07) in SELOGIC control equation SV07 (see SELogic Control Equation Variable Timer Input Equations on page SET.5 of the SEL-734 Settings Sheets):

SV07 = (SV07 OR OUT101) AND (OUT102 OR OUT401)

SVn SVn

SVnT

SELOGIC Variable/Timer Input Settings

MeterWord Bits

SVnPU

SVnDO

Table 8.2 Operator Precedence

Operator Description

( ) Parenthesis

NOT Boolean Complement

R_TRIG Rising Edge Trigger

F_TRIG Falling Edge Trigger

<, >, <=, >= Analog Comparison

= Analog Equality Check

<> Analog Inequality Check

AND Boolean AND

OR Boolean OR

8.11


LogicMath Variables

Figure 8.11 Example Use of SELOGIC Variables/Timers

Math VariablesThirty-two SELOGIC control equation math variables are available. SELOGIC control equation math variables are math calculation storage results. Use the MAT command to view the results of each math variable.

Use math variables in fixed-form programming to store the results of math calculations as arguments in math calculations and comparisons. Available math operators are plus (+), minus (–), multiply (*), and divide (\). Example 8.1 illustrates SELOGIC control equation math variable usage.

Math variable analog quantities use secondary values

EXAMPLE 8.1 SELOGIC Control Equation Math Variables

The equations below show fixed-form SELOGIC control equation programming examples that use SELOGIC control equation math variables. Each line has a comment after the # that provides additional description.

MV01 := 378.62 # Store 387.62 in MV01

MV09 := 5 + VA_MAG # Store sum of 5 and A-phase secondary voltage in MV09

Math Error Detection If a math operation results in an error, the SEL-734 turns on the math error bit, MATHERR, in the Meter Word. A settings change or the STATUS SC command provides reset for this bit. For example, if you attempt to divide a value by zero, the math error bit will be asserted until you clear the bit with a STATUS SC command or change settings.

Analog Control ValuesOverview Analog control values (ACVs) provide a means of easily adjusting and

defining limits and thresholds used in SELOGIC control equations. Thirty-two ACVs are available for use with SELOGIC expressions and for display. ACVs are nonvolatile analog registers that you may modify through the front panel, DNP, or ACSELERATOR QuickSet® SEL-5030 Software. ACVs are useful for quick and easy adjustment of control limits and threshold settings.

User-Defined Alias Use the Analog Control Value Alias (ACVA) setting to customize a label under the SET/SHOW menu on the front panel. For example, assume that you are using ACV registers to implement overcurrent thresholds of a control algorithm. You can set the ACVA setting to OVERCURRENT THRESHOLDS.

SV06PU

SV06D0

SV07PU

SV07D0

SV06

SV07

OUT101

OUT102

OUT103

OUT401

OUT101

OUT102

OUT401

8.12


LogicAnalog Control Values

Use the ACVAnn settings to customize labels for each ACV register. Following the example above, you might choose to set ACVA01 to PHASE A OVERCURRENT, SEC AMPS and ACVA02 to PHASE B OVERCURRENT, SEC AMPS, etc.

By default, the aliases are set to the Analog Quantity name of the ACV register, ACVnn.

Figure 8.12 shows the menu aliases of this example.

Figure 8.12 ACV Register Alias Example

User-Defined Range Use the ACVnnMAX and ACVnnMIN settings to limit the range of values that ACV registers accept. The SEL-734 returns an out-of-range error if an attempt is made to set an ACV outside of this range. Continuing the overcurrent threshold example, you might choose to set the valid range from 0 to 21.

Write Values to an ACV Register

You can change the value of an ACV using three different methods, as listed below:

➤ Send new settings

➤ Use the Set/Show menu on the front panel

➤ Send a DNP3 Analog Output Write exchange

On any attempt to write a value outside of the range defined by ACVnnMIN and ACVnnMAX, the SEL-734 returns an out-of-range error.

Send New SettingsYou may change the ACV register value by changing the Logic settings. The Analog Control Value (ACVnn) setting sets the value of the ACV register each time you send logic settings to the device.

Configure Register Through the Front-Panel MenuYou can change the ACV register value through the front-panel menu. To do this, follow the steps below.

Step 1. Press the ENT pushbutton.

Step 2. From the MAIN menu, navigate to the Set/Show menu.

SET/SHOWOVERCURRENT THRESHOLDSMeter SettingsPort SettingsGlobal SettingsFront Panel SettingsDate/TimeSet Password

PHASE A OVERCURRENT, SEC AMPS

20.00

NOTE: The SEL-734 applies new ACV values to all interfaces when writing to the ACV from any interface.

8.13


LogicAnalog Control Values

Step 3. From the Set/Show menu, select the Analog Control Values group.

The Analog Control Values alias is the default setting string. When the ACVA setting is set to something other than the default string, the configured alias displays instead of the default string.

Step 4. Select the desired ACV register.

Step 5. Enter the 2AC password.

Step 6. Use the directional buttons on the keypad to adjust the value within the valid range, as determined by the ACVnnMAX and ACVnnMIN settings.

Step 7. Press ESC to exit the menu.

Step 8. Save the changes when prompted.

Figure 8.13 shows the menu structure to access the ACV settings from the front panel. Note that the figure shows the ACV aliases with default labels.

Figure 8.13 Change ACV Register Value From the Front Panel

Send a DNP3 Analog Output Write ExchangeOften, the DNP master automatically and dynamically controls the operating limits and thresholds of the control algorithm remotely. The ability to modify ACV values via DNP allows you to set up such a system with the SEL-734.

To change an ACV register value via DNP3, first map the ACV register to the Analog Output DNP map. Follow the procedure below to configure an ACV register to change with DNP3.

Step 1. Map the desired ACV registers to the analog output objects of the DNP map.

Step 2. Configure a communications port for DNP3.

MAINMeterEventsTargetsStatusSet/Show

734Meter

SET/SHOWAnalog Control ValuesMeter SettingsPort SettingsGlobal SettingsFront Panel SettingsDate/TimeSet Password

ACV01= 0.00ACV02= 0.00ACV03= 0.00ACV04= 0.00ACV05= 0.00

8.14


LogicCounter Variables

Step 3. Establish DNP3 communications.

Step 4. Write to the DNP point of the desired ACV register using a DNP Object 41 command.

For any DNP3 write command sent with a response request, the SEL-734 returns a code in the Control Status block. Table 8.3 defines the meaning of the code returned and describes typical scenarios for each code.

Counter VariablesSELOGIC control equation counters are up- or down-counting elements, with a reset input and two outputs:

➤ one asserts when the programmable count limit is reached

➤ the other asserts when the counter is at position zero

These counter elements conform to the standard counter function block #3 in IEC 1131-3 First Edition 1993-03 International Standard for Programmable Controllers - Part 3: Programming Languages.

Table 8.4 describes the Boolean input settings, counter value setting, and Boolean outputs of the counters. Note that n = 01 to 32.

Table 8.3 Error Codes of DNP3 Writes to ACV Registers

Error Code Value

Definition Description

0 Value written The value sent was successfully written to the SEL-734.

3 Format error The value sent is outside of the range specified by the associated ACVnnMAX and ACVnnMIN settings.

4 Not supported The DNP point is not in the map.

5 Point already active The ACV register is being configured through a different interface, either settings or the front panel.

Table 8.4 Counter Inputs and Outputs (Sheet 1 of 2)

Name Type Description

SCnCV Setting, Current Value

Current Value of counter SCn. Use this setting to preload a value into the counter.

SCnPV Setting, Preset Value

Maximum value that the counter will reach before freezing and the value that is loaded into the counter when the Load Preset result is evaluated as TRUE.

SCnR SELOGIC Equation, Reset

Logic equation that when TRUE resets the counter to zero.

SCnLD SELOGIC Equation, Load Preset

Logic equation that when TRUE loads the counter with the Preset Value.

SCnCU SELOGIC Equation, Count Up

Logic equation that when TRUE increments the value of the counter by one.

SCnCD SELOGIC Equation, Count Down

Logic equation that when TRUE decrements the value of the counter by one.

SCnQU Output, Word Bit Word bit asserts when the counter Current Value equals the Preset Value.

8.15


LogicCounter Variables

Example 8.2 illustrates how to use the SELOGIC control equation counters to limit the demand by starting an on-site diesel generator.

EXAMPLE 8.2 Using Counters to Control Generator Starting via Load Monitoring

When the three-phase demand is greater than 100 kW for greater than 10 minutes, the diesel generator should start to pick up demand. The generator should be started in 5 minutes when demand is > 125 kW. Also, if the demand is greater than 150 kW, the diesel generator should start immediately. In order to achieve this function, make the following settings:

ESC := 1

ESV := 10

SC01PV := 60

SC01R := IN401 # disable the starting of the generator if desired

SC01LD := IN402 OR (MW3DI > 150) # start the generator immediately

SV10 := NOT(SV10T) # 10 second period

SC01CU := R_TRIG SV10 AND (MW3DI > 100) OR F_TRIG SV10 AND (MW3DI > 125) # increment counter SC01, faster when the demand is higher than 125.00

SC01CD := R_TRIG SV10 AND (MW3DI < 100) # decrement counter SC01 when the demand is below 100.00

OUT402 := (SC01 > 48) # warning that diesel generator is about to start

OUT401 := SC01QU # start generator signal

Figure 8.14 SELOGIC Variable SV10 Timing Logic

Because demands are slow changing values, it does not make sense to check them continuously. The ten-second period on SV10T makes the preset value setting easier to determine.

Figure 8.15 is provided as a reference to this example.

SCnQD Output, Word Bit Word bit asserts when the counter Current Value equals zero.

SCn Output, Analog Value

Present counter value. Use with any analog comparison in SELOGIC and view using the COU command.

Table 8.4 Counter Inputs and Outputs (Sheet 2 of 2)

Name Type Description

NOTE: SCn is stored in volatile memory and is lost when the meter loses power.

SV10 SV10T5.00

5.00

Preset Value 10 minutes 60 s/minute• 10 x/count

------------------------------------------------------------- 60 s/count= =

8.16


LogicKYZ Outputs

Figure 8.15 SELOGIC Control Equation Counter Example

KYZ OutputsThe SEL-734, using settings KYZD1 through KYZD4, outputs the integrated quantities shown in Table 8.5. Note that Form 5 meters only accept 3-phase quantities. The meter allows for as many as four integrated values to be output to Form A contacts. Solid state output contacts are recommended for KYZ operation.

The availability of the KYZ output is determined by the EKYZ setting (see Table 8.6).

Setting EKYZ = N disables all KYZ elements, and the output Meter Word bits are deasserted.

3-ph

Dem

and

(kW

)

100

125

0

3691215182124273033363942454851545760

SC01

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

TIME (minutes)

9 6

24

48

60

OUT401

OUT402

Table 8.5 KYZ Energy Values

Energy KYZ Energy Valuesa

a Where n = A, B, C, or 3

Real Energy: KWHnI

KWHnO

Apparent Energy: KVAHnI

KVAHnO

Reactive Energy: KVRHnI_LG

KVRHnI_LD

KVRHnI

KVRHnO_LG

KVRHnO_LD

KVRHnO

8.17


LogicKYZ Outputs

The number of KYZ triggers is determined by user settings KEn, KEn_SCALE, KEn_UNITS, and can be calculated using Equation 8.1:

Equation 8.1

Any remainder left over after the KYZ-triggers calculation is carried over to the next calculation.

KYZ energy data can be collected using two methods. The first uses a pickup that records the rising edge of a pulse; the second records the rising and falling edges. The KYZ outputs of the SEL-734 are designed for compatibility with a pickup that records the rising and falling edge (see Figure 8.16). If using a rising edge pickup, divide the required Ke by two.

Table 8.6 KYZ Output Settings and Ranges

Setting Definition Range

EKYZ Enables KYZ elements N, 1–4

KEn_SCALE Determines output of KEn in Primary or Secondary

PRI, SEC

KEn Trigger initiator output constant 0.0001–9999

KEn_UNIT Trigger output units UNITY, KILO, MEGA

KYZDn Energy value to be output Energy Quantities (see Table 8.5)

KYZPWn KYZn Pulse Width, determines the minimum pulse width

25, 50, 75, 100 ms

where:Ke = KEn • UNITS / trigger

where:

UNITS = 1 if KEn_UNITS = UNITY = 1000 if KEn_UNITS = KILO = 1000000 if KEn_UNITS = MEGA

t = time (typically 1 second)Rprevious = Remainder from the previous calculation of the number of

KYZ triggers

Number of KYZ TriggersTotal Energy during t + Rprevious

Ke---------------------------------------------------------------------------------=

8.18


LogicKYZ Outputs

Figure 8.16 KYZ Pulse Pickup

The pulse width, KYZPWn, determines the minimum length after each state transition, and therefore, the maximum number of pulses per second. The possible settings for KYZPWn are 25, 50, 75, and 100 ms according to your specification.

The first diagram in Figure 8.16 shows energy triggers asserting after the KYZ Pulse Width time period. The second diagram in Figure 8.16 shows energy triggers asserting prior to the KYZ Pulse Width time period. If more pulses are generated in the second than can be pulsed in one second (as shown in the second diagram of Figure 8.16), the remaining triggers are added to the queue for the following second.

To output the energy quantity KWHAO (A-phase kilowatt-hours out) in kilowatt-hours primary, make the following settings:

EKYZ = 1

KE1_SCALE = PRI

KE1 = 1.8

KE1_UNIT = KILO

KYZD1 = KWHAO

KYZPW1 = 25

SET L <Enter>

OUT401 = R_TRIG KYZD1 OR F_TRIG KYZD1

For every 1.8 kWh primary measured on A-phase out, Meter Word bit KYZD1 changes state and maintains the new state for at least the time defined by KYZPW1 (25 ms in this case). OUT401 asserts on each rising and falling edge of Meter Word bit KYZD1 and deasserts after approximately 25 ms (no correlation with KYZPW1).

KYZDn Meter Word Bit State

t1 = KYZPWn KYZ Minimum Pulse Width (ms)

Trigger

Deasserted

Deasserted

Asserted

KYZDn Meter Word Bit State

Trigger

Asserted

t1t1t1 t1

8.19


LogicOutput Contacts

Other KYZ triggers are output following the above example settings.

Total energy at the receiving end of these triggers can be calculated using Equation 8.2:

If KEn_SCALE is set to SEC:Total Energy (Pri.) = Number of triggers • CTR • PTR • Energy per triggerTotal Energy (Sec.) = Number of triggers • Energy per trigger

If KEn_SCALE is set to PRI:Total Energy (Pri.) = Number of triggers • Energy per triggerTotal Energy (Sec.) = Number of triggers • Energy per trigger/(CTR • PTR)

Equation 8.2

Output ContactsFigure 8.17 shows the example operation of output contact Meter Word bits (e.g., OUT401 through OUT402) resulting from the following:

➤ SELOGIC control equation operation (e.g., SELOGIC control equation settings OUT401 through OUT402 in Figure 8.14)

or

➤ PULSE command execution

The output contact Meter Word bits control the output contacts (e.g., output contacts OUT401 through OUT402 in Figure 8.17).

Alarm logic SALARM (software alarm Meter Word bit) and HALARM (hardware alarm Meter Word bit) are available to make an alarm output contact. OUT103 is set to OUT103 = NOT (SALARM OR HALARM) by default.

Figure 8.17 is used for following discussion/examples.

Factory Settings Example

In the factory SELOGIC control equation settings, three output contacts are used:

OUT101 = 0 (output contact OUT101 not used—set equal to zero)

OUT102 = 0 (output contact OUT102 not used—set equal to zero)

OUT103 = NOT (SALARM OR HALARM) (SALARM, HALARM; software/hardware alarms)

Operation of Output Contacts for Different Output Contact Types

Output Contacts OUT101 Through OUT103 The execution of the serial port command PULSE n (n = OUT101–OUT103) asserts the corresponding Meter Word bit OUTm (m = 101–103) to logical 1. The assertion of SELOGIC control equation setting OUTm to logical 1 also asserts the corresponding Meter Word bit OUTm to logical 1.

The assertion of Meter Word bit OUTm to logical 1 causes the energization of the corresponding output contact OUTm coil. Depending on the contact type (a or b), the output contact closes or opens. An a contact output is open when the output contact coil is de-energized and closed when the output contact coil is energized. A b contact output is closed when the output contact coil is de-energized and open when the output contact coil is energized.

8.20


LogicAnalog Output

Output contact pickup/dropout time is 8 ms for electromechanical and less than 500 µs for solid-state contacts.

Configuring a Contact Output as an Alarm Output ContactRefer to Figure 8.17 and Meter Self-Tests on page 12.12.

The SALARM and/or HALARM bit may be used to develop an alarm output contact. The alarm logic SALARM and/or HALARM keeps the alarm output contact coil energized. Depending on the output contact type (a or b), the SALARM and/or HALARM closes or opens the contact.

The Meter Word bit SALARM and/or HALARM is deasserted to logical 0 when the meter is operational. Also, when the meter enters Access Level 2, the SALARM Meter Word bit momentarily asserts to logical 1.

The HALARM Meter Word bit asserts momentarily for hardware warnings and asserts permanently for hardware failures.

Figure 8.17 Logic Flow for Example Output Contact Operation

Analog OutputThe optional analog output/digital output (AO/DO) card for the SEL-734 provides four analog outputs (AO401–AO404) and four solid-state digital outputs (OUT401–OUT404). Each analog output acts as a programmable transducer. The SEL-734 measures a user-selectable analog quantity and produces a dc current between ±1.2 mA or ±24.0 mA that is proportional to the measured value.

Analog outputs provide ±0.25% accuracy for the following quantities: xx_RMS, xx_AVG, xx_U, all Demand/Peak, Energy, and Max/Min.

The meter updates analog outputs every 100 milliseconds or faster. The analog outputs automatically scales the output quantities as follows:

➤ Power and Energy: Mega units

➤ Voltage: kilovolts

➤ Current: Amps

Table 8.7 describes each analog output setting (xx = 01–04) When AOxxAQ is set to OFF, all other settings are hidden.

Serial PortCommands

MeterWord Bits

SELOGICControl

EquationsSettings

ExampleMeter

Word BitStates

OutputContact

Coil StatesOutput

Contacts

PULSE OUT401

PULSE OUT402

OUT401 de-energized

energized

OUT401 (a)

OUT402 OUT402 (a)

OutputContactTerminal

States

logical 0

logical 1

open

closed

OUT401

OUT402

8.21


LogicAnalog Output

Figure 8.18 illustrates an example in which we set the SEL-734 analog output AO01 to report instantaneous three-phase real power (MW3) to a remote terminal unit (RTU). The RTU expects a ±1 mA input from the SEL-734.

Figure 8.18 Example SEL-734 Connected to an RTU

For our example, we determine that our load has a maximum delivered power of 1000 kW and maximum received power of 1000 kW. The SEL-734 reports three-phase real energy as plus (+) for delivered and minus (–) for received power. We therefore set Analog Quantity Low (AO01AQL) to –1 MW and Analog Quantity High (AO01AQH) to +1 MW. Next, we establish output current levels by setting Low Analog Output Value (AO01L) to –1.000 and High Analog Output Value (AO01H) to +1.000. Table 8.8 lists the connection details.

Figure 8.19 illustrates the corresponding settings in the ACSELERATOR QuickSet® SEL-5030 Software.

Table 8.7 Analog Output Settings

Setting Name

Setting Range Description

AOxxAQ OFF, Valid Analog Quantities Input. Select any valid analog quantity. See Appendix H: Analog Quantities for a list of all applicable quantities.

AOxxAQL –2147483647.000 to 2147483647 Input limit. Sets the measured value that will create the minimum current output for the selected analog quantity in primary units.a

a Analog quantities are scaled as follows: energy and power values are in mega units, voltages are in kilo units, and currents are in unity units.

AOxxAQH –2147483647.000 to 2147483647 Input limit. Sets the measured value that will create the maximum current output for the selected analog quantity in primary units.a

AOxxL –1.200 to 1.200 mA

or

–24.000 to +24.000 mA

Output limit. Specifies the minimum output current value representing the setting AOxxAQL.

AOxxH –1.200 to 1.200 mA

or

–24.000 to +24.000 mA

Output limit. Specifies the maximum output current value representing the setting AOxxAQH.

Table 8.8 Example Connection Details

Input Range (Pri.) Analog Output

–1000 kW –1 mA

0 Watts 0 mA

+1000 kW +1 mA

SEL-734

RTUAO01

8.22


LogicRotating Display

Figure 8.19 ACSELERATOR QuickSet Analog Output Settings

Set other analog quantities similarly.

Rotating DisplayThere are 32 displays available in the SEL-734. Each display has two complementary screens (e.g., points) available.

General Operation of Rotating Display Settings

SELOGIC control equation display point setting DPnn (nn = 01 through 32) controls the display of corresponding, complementary text settings:

DPnn_1 (displayed when DPnn = logical 1)

DPnn_0 (displayed when DPnn = logical 0)

Make each text setting through the serial port by using the command SET F. View these text settings by using the serial port command SHO F (see Section 9: Settings and Section 10: Communications). These text settings are displayed on the SEL-734 front-panel display on a time-variable rotation through use of the front-panel setting SCROLD.

The following factory settings examples use optoisolated inputs IN101 and IN102 in the display points settings. Remote bits (RB01 through RB16) and any other combination of Meter Word bits in a SELOGIC control equation setting can also be used in display point setting DPnn.

Displaying Values on the Rotating Default Display

Each display point setting contains one or more of the following: Analog Quantity, Meter Word bit, user-defined text, and/or user-defined numerical formatting. Meter Word bits and Analog Quantities are displayed as default form or as user-defined text.

Display point setting strings have a maximum length of 64 characters. Quotes are optional and are required only if the given string contains commas or spaces. If the entire string is empty, then that display point is hidden.

8.23



Name—Displays the given entry exactly as seen on the setting line (name, value, and units). Name is any valid analog quantity or a Meter Word bit. See Section 9: Settings and Appendix H: Analog Quantities for valid display point names.

Name, “Alias”—Display given entry, replacing Name with the given Alias string.

Name, “Alias,” “Set String,” “Clear String”—This format requires that Name be a Meter Word bit. Display the given entry as Alias. If the Meter Word bit state is asserted (logical 1), display the Set String as the value. If the Meter Word bit state is deasserted (logical 0), display the Clear String as the value. Alias, Set String, or Clear String can be empty. If Alias is empty, then only the Set String or Clear String will be displayed. If either Set String or Clear String are empty, then the item will not be visible when the bit matches that state. If an empty line is required in this case (instead of hiding the line), then empty curly braces ({}) should be used for the Set String or Clear String. Alias and Set String/Clear String are all displayed on the same line of the front panel display.

Name, “User text {numerical formatting}”—Display given entry, replacing Name with User text and displaying the value of Name in the user-defined format {width.dec,scale}, {numerical formatting}. The value is scaled by “scale,” formatted with a total digit width “width” and “dec” decimal places as defined in {numerical formatting} ({width.dec,scale}). Name can be either an analog quantity or a Meter Word bit. The width value should include the decimal point and sign character, if applicable. The “scale” is 1 if omitted. If the numeric value is smaller than the field size requested, the field is padded with spaces to the left of the number. If the numeric value will not fit in the given field width, the field grows (to the left of the decimal point) to accommodate the number. All user formatted display points occupy one line on the display. Multiple lines are simulated by using multiple display points.

Set Name to 1 to create fixed text, placing the text in brackets as the Alias or empty brackets to leave a blank line.

Table 8.9 Display Point Test Definitions

Term Definition

Name Any valid Analog Quantity or Meter Word bit you wish to display

Alias An alternate name (string) displayed, replacing the Analog Quantity or Meter Word bit assigned in Name

Set String A user-defined string displayed when the Meter Word bit assigned in Name asserts (logical 1)

Clear String A user-defined string displayed when the Meter Word bit assigned in Name deasserts (logical 0)

User text {numerical formatting}

A user-defined text string (Alias) replacing the {numerical formatting} with {width.dec,scale} where the value of Name is scaled by “scale”, formatted with total width “width” and “dec” decimal places. Maximum width and dec are 20 digits.

8.24



Values Displayed for Incorrect Settings

If the display point setting string is not formatted correctly, one of the following errors will replace the display point on the rotating display:

Syntax Error in DPnn_n—The setting string syntax is incorrect.

Name Error in DPnn_n—The name in the setting string is not a valid Analog Quantity or Meter Word bit.

User Format Error in DPnn_n—The user formatting for the display point value is not valid.

For example:

=>>SET F <Enter>

DP01 = 0

DP01_0 = IN101,METER WORD BIT IN101” (missing “ before METER)

DP02 = 0

DP02_0 = MVSH3I,”3 PHASE APPARENT ENERGY IN” (MVSH3I is not a valid name)

DP03 = 0

DP03_0 = MWH30,”WATT HOURS 3P OUT={4,100,2}” ({4,100,2} is not a valid format)

Table 8.10 Display Point Formatting

Display Point Setting Format Example Display Point Setting Example Display

DPnn_n := Name IN101 IN101=0

DPnn_n := Name IA_MAG IA MAG (A)1234.567

DPnn_n := Name MVAADI MVAADI (MVA)1234.56

DPnn_n := Name,Alias MVAADO,“APPARENT DEM. A” APPARENT DEM. A (MVA)1234.56

DPnn_n := Name,Alias,Set String,Clear String SV01,“CONTROL”,ON,OFF CONTROL=ON

CONTROL=OFF

DPnn_n := Name,Alias,Set String SV02,BREAKER,TRIPPED, BREAKER=TRIPPED

Entry is hidden

DPnn_n := Name,,{},Clear String RB03,,{},“OVERCURRENT” Empty line displayed

OVERCURRENT

DPnn_n := Name,“User {numerical width} text” MVRADI,“VAR DEM {4}MVAR” VAR DEM 1234MVAR

DPnn_n := Name,“User text ={numerical width.dec}” MVR3PO,“REACT P OUT={4.1}” REACT P OUT= 12.1a

DPnn_n := Name,“User {numerical width} text” ICD,“C DEMAND={5}” C DEMAND= 1234a

DPnn_n := Name,“User text ={width.dec,scale}” ICD,“C DEMAND={4.2,0.001}kA” C DEMAND=1.23 kA

DPnn_n := Name,“User text = {width,scale}” MVRHAO,“KVARH OUT A={4,1000}” KVARH OUT A=1234

DPnn_n := Name, {Alias} 1,“FIXED TEXT” FIXED TEXT

DPnn_n := 1,{} 1,{} Empty line

a Note: Numbers smaller than the designated width do not have leading zeros, but have blank spaces.

8.25



Logic settings DP01, DP02, DP03 are permanently set to logical 0. This causes the corresponding DPnn_0 value to rotate in the display. With the DPnn_0 setting problems just discussed, the meter displays the appropriate error, one per line on the display:

Syntax Error in DP01_0

Name Error in DP02_0

User Format Error in DP03_0



Section 9Settings

OverviewThis section explains how to use the SET and SHOWSET serial port commands to make settings changes in the SEL-734. Meter Word bits tables for SELOGIC® control equations are also included, as well as settings explanations. Finally, the section concludes with the SEL-734 Settings Sheets.

Change or view settings with the SET and SHOWSET serial port commands. Table 9.1 lists the serial port SET commands.

You can view settings with the respective serial port SHOWSET commands (SHO, SHO L, SHO E, SHO G, SHO R, SHO F, SHO P). See the SHO Command (Show/View Settings) on page 10.24.

Settings Changes Via the Serial PortSee Section 10: Communications for information on serial port communications and meter access levels. The SET commands in Table 9.1 operate at Access Level 2 (the =>> prompt). To change a specific setting, enter the command:

SET n s TERSE

When you issue the SET command, the meter presents a list of settings, one at a time. Enter a new setting, or press <Enter> to accept the existing setting. Editing keystrokes are shown in Table 9.2.

Table 9.1 Serial Port SET Commands

CommandSettings

Type Description

SET Meter Enables, Transformer ratios, Timers, etc.

SET L Logic SELOGIC control equations

SET E Energy Preset Preload energy values

SET G Global Phase rotation, date format, Watt/VAR angle cutoff, synchrophasor, ASCII report scaling, and input debounce timers.

SET R Reports Events Recorder trigger conditions, Load Profile settings, and Fast Message settings.

SET F Front Panel Front-panel default display settings.

SET P n Port Serial port settings for Serial Port n (n = F, 1, 2, 3, or 4).

where:n = L, E, G, R, F, or P (parameter n is not entered for the meter settings).s = the name of the specific setting you wish to jump to and begin setting.

If s is not entered, the meter starts at the first setting.TERSE = instructs the meter to skip the SHOWSET display after the last setting.

Use this parameter to speed up the SET command. If you wish to review the settings before saving, do not use the TERSE option.

9.2


SettingsMeter Word Bits (Used in SELOGIC Control Equations)

The meter checks each entry to ensure that it is within the setting range. If it is not, an Out of Range message is generated, and the meter prompts for the setting again.

When all the settings are entered, the meter displays the new settings and prompts for approval to enable them. Answer Y <Enter> to enable the new settings.

When changes are made to the global, SER, front-panel, meter, or logic settings (see Table 9.1), the meter disables while it saves the new settings and pulses the SALARM bit for approximately one second. If Logic settings are changed, the meter can be disabled for as long as 15 seconds.

Meter Word Bits (Used in SELOGIC Control Equations)Meter Word bits are used in SELOGIC control equation settings. Numerous SELOGIC control equation settings examples are given in Section 3: PC Software through Section 8: Logic. SELOGIC control equation settings can also be set directly to 1 (logical 1) or 0 (logical 0). Appendix D: Setting SELogic Control Equations gives SELOGIC control equation details, examples, and limitations.

The Meter Word bit row numbers correspond to the row numbers used in the TAR command (see TAR Command (Display Meter Element Status) on page 10.26).

Table 9.2 SET Command Editing Keystrokes

Press Key(s) Results

<Enter> Retains setting and moves to the next setting.

^ <Enter> Returns to previous setting.

< <Enter> Returns to previous setting section.

> <Enter> Moves to next setting section.

END <Enter> Exits editing session, then prompts you to save the settings.

<Ctrl+X> Aborts editing session without saving changes.

Table 9.3 SEL-734 Meter Word Bits (Sheet 1 of 3)

TAR Row

Index Range

7 6 5 4 3 2 1 0

0 1606–1600a LED6 LED5 LED4 LED3 LED2 LED1 *b ENABLE

1 7–0 FALARM HARM02 HARM03 HARM04 HARM05 HARM06 HARM07 HARM08

2 15–8 HARM09 HARM10 HARM11 HARM12 HARM13 HARM14 HARM15 RESET

3 23–16 SAGA SAGB SAGC SAG3P SWA SWB SWC SW3P

4 31–24 SAGAB SAGBC SAGCA ITIC_ND SWAB SWBC SWCA ITIC_PR

5 39–32 INTA INTB INTC INT3P INTAB INTBC INTCA ITIC_SR

6 47–40 QDEM PDEM GDEM NDEM RSTDEM EOIP RSTPKDM MATHERR

7 55–48 FLTBLK FAULT DFAULT TEST IRIGOK SSI_EVE MIU LOWBAT

8 63–56 SESNCH DSTCH * * * RATECH * SETCH

9 71–64 27Ac 27Bc 27Cc * * * TSOK PMDOK

10 79–72d OUT101 OUT102 OUT103 OUT401e OUT402e OUT403e OUT404e SALARM

11 87–80 IN101 IN102 IN401f IN402f IN403f IN404f * HALARM

12 95–88 KYZD1 KYZD2 KYZD3 KYZD4 KYZDT RSTENGY PREDAL *

13 103–96 RMB8A RMB7A RMB6A RMB5A RMB4A RMB3A RMB2A RMB1A

9.3



14 111–104 TMB8A TMB7A TMB6A TMB5A TMB4A TMB3A TMB2A TMB 1A

15 119–112 RMB8B RMB7B RMB6B RMB5B RMB4B RMB3B RMB2B RMB1B

16 127–120 TMB8B TMB7B TMB6B TMB5B TMB4B TMB3B TMB2B TMB1B

17 135–128 LBOKB CBADB RBADB ROKB LBOKA CBADA RBADA ROKA

18 143–136 SV01 SV02 SV03 SV04 SV01T SV02T SV03T SV04T




22 175–168 RB01 RB02 RB03 RB04 RB05 RB06 RB07 RB08

23 183–176 RB09 RB10 RB11 RB12 RB13 RB14 RB15 RB16

24 191–184 LT01 LT02 LT03 LT04 LT05 LT06 LT07 LT08


26 207–200 SET01 SET02 SET03 SET04 SET05 SET06 SET07 SET08

27 215–208 RST01 RST02 RST03 RST04 RST05 RST06 RST07 RST08



30 239–232 SC01QU SC02QU SC03QU SC04QU SC05QU SC06QU SC07QU SC08QU

31 247–240 SC01QD SC02QD SC03QD SC04QD SC05QD SC06QD SC07QD SC08QD



34 271–264 T06_LED T05_LED T04_LED T03_LED T02_LED T01_LED * *

35 279–272 ER1 ER2 ER3 FREQY NEWEVNT * * *

36 287–280 DP01 DP02 DP03 DP04 DP05 DP06 DP07 DP08


38 303–296 SC01R SC02R SC03R SC04R SC05R SC06R SC07R SC08R

39 311–304 SC01LD SC02LD SC03LD SC04LD SC05LD SC06LD SC07LD SC08LD

40 319–312 SC01CU SC02CU SC03CU SC04CU SC05CU SC06CU SC07CU SC08CU

41 327–320 SC01CD SC02CD SC03CD SC04CD SC05CD SC06CD SC07CD SC08CD





46 367–360 EQA1 EQA2 EQA3 EQA4 EQB1 EQB2 EQB3 EQB4

47 375–368 EQC1 EQC2 EQC3 EQC4 EQ3P1 EQ3P2 EQ3P3 EQ3P4

48 383–376 PB01g PB02g PB03g PB04g * * * *

49 391–384g T14_LEDg T13_LEDg T12_LEDg T11_LEDg T10_LEDg T09_LEDg T08_LEDg T07_LEDg






TAR Row

Index Range

7 6 5 4 3 2 1 0

9.4























74 591–584 * * * * * * * *

75 599–592 * * * * * * * *

76 607–600 * * * * * * * *

a The asterisk in column 1 is not mapped in this case only; therefore, index 1601 corresponds to LED1.b Not used.c For Form 5 meters, the 27 element Word Bits assert when VAB, VBC, or VCA are less than the 27P1P threshold.d All contact outputs can be type a or type b. See Figure 8.17 for more information on the operation of output contacts OUT101–OUT103 and

OUT401–OUT404.e OUT401–OUT404 and IN401–IN404 are available only on model 0734ES2-6X.f See Figure 8.1 and Figure 8.2 for more information on the operation of optoisolated inputs.g PB01–PB04 and T07_LED–T14_LED are available only on model 0734B.


TAR Row

Index Range

7 6 5 4 3 2 1 0

9.5



Meter Word Bits (Used in SELOGIC Control Equations)

Table 9.4 SEL-734 Meter Word Bit Definitions (Sheet 1 of 17)

Row Bit Definition

1 7 FALARM Harmonic threshold alarm

6 HARM02 Second harmonic threshold

5 HARM03 Third harmonic threshold

4 HARM04 Fourth harmonic threshold

3 HARM05 Fifth harmonic threshold

2 HARM06 Sixth harmonic threshold

1 HARM07 Seventh harmonic threshold

0 HARM08 Eighth harmonic threshold

2 7 HARM09 Ninth harmonic threshold

6 HARM10 Tenth harmonic threshold

5 HARM11 Eleventh harmonic threshold

4 HARM12 Twelfth harmonic threshold

3 HARM13 Thirteenth harmonic threshold

2 HARM14 Fourteenth harmonic threshold

1 HARM15 Fifteenth harmonic threshold

0 RESET RESET bit asserted

3 7 SAGA A-phase voltage sag element

6 SAGB B-phase voltage sag element

5 SAGC C-phase voltage sag element

4 SAG3P Three-phase voltage sag element

3 SWA A-phase voltage swell element

2 SWB B-phase voltage swell element

1 SWC C-phase voltage sag element

0 SW3P Three-phase voltage swell element

4 7 SAGAB Phase-to-phase AB voltage sag element

6 SAGBC Phase-to-phase BC voltage sag element

5 SAGCA Phase-to-phase CA voltage sag element

4 ITIC_ND CBEMA/ITIC no damage region

3 SWAB Phase-to-phase AB voltage swell element

2 SWBC Phase-to-phase BC voltage swell element

1 SWCA Phase-to-phase CA voltage swell element

0 ITIC_PR CBEMA/ITIC prohibited region

5 7 INTA A-phase voltage interrupt element

6 INTB B-phase voltage interrupt element

5 INTC C-phase voltage interrupt element

4 INT3P Three-phase voltage interrupt element

3 INTAB Phase-to-phase AB voltage interrupt element

2 INTBC Phase-to-phase BC voltage interrupt element

1 INTCA Phase-to-phase CA voltage interrupt element

0 ITIC_SR CBEMA/ITIC safe region

6 7 QDEM Negative-sequence demand current above pickup setting QDEM

6 PDEM Phase demand current above pickup setting PDEM

5 GDEM Residual ground demand current above pickup setting GDEM

4 NDEM Neutral ground demand current above pickup setting NDEM

3 RSTDEM Present demand value reset

2 EOIP End of Interval Pulse asserted (demand)

1 RSTPKDM Peak demand value reset

0 MATHERR Math error asserted for error in math variables

7 7 FLTBLK Fault block asserted

6 FAULT Fault bit asserted

5 DFAULT Delayed fault asserted

4 TEST Test mode bit asserted

3 IRIGOK IRIG-B input OK

2 SSI_EVE Detect SSI event within processing interval

1 MIU Modem in use

0 LOWBAT Low real-time clock battery warning

8 7 SESNCH TOU season change bit asserted

6 DSTCH DST change bit asserted

5 * Not used

4 * Not used

3 * Not used

2 RATECH Rate change bit asserted

1 * Not used

0 SETCH Settings change bit asserted

9 7 27A A-phase instantaneous undervoltage element

6 27B B-phase instantaneous undervoltage element

5 27C C-phase instantaneous undervoltage element

4 TSOK Time stamp OK

3 * Not used.

2 * Not used.

1 * Not used.

0 PMDOK Measurement data OK


Row Bit Definition

9.6



10 7 OUT101 Output contact OUT101 asserted

6 OUT102 Output contact OUT102 asserted






0 SALARM Software alarm asserted

11 7 IN101 Optoisolated input IN101 asserted

6 IN102 Optoisolated input IN102 asserted





1 * Not used.

0 HALARM Hardware alarm

12 7 KYZD1 KYZ pulse number 1

6 KYZD2 KYZ pulse number 2



3 KYZDT KYZ pulse test

2 RSTENGY Energy registers reset

1 PREDAL Predictive demand alarm

0 * Not used.

13 7 RMB8A Channel A, received bit 8

6 RMB7A Channel A, received bit 7







14 7 TMB8A Channel A, transmit bit 8

6 TMB7A Channel A, transmit bit 7








Row Bit Definition

15 7 RMB8B Channel B, received bit 8

6 RMB7B Channel B, received bit 7







16 7 TMB8B Channel B, transmit bit 8

6 TMB7B Channel B, transmit bit 7







17 7 LBOKB Channel B, looped back ok

6 CBADB Channel B, channel unavailability over threshold

5 RBADB Channel B, outage duration over threshold

4 ROKB Channel B, received data ok

3 LBOKA Channel A, looped back ok

2 CBADA Channel A, channel unavailability over threshold

1 RBADA Channel A, outage duration over threshold

0 ROKA Channel A, received data ok

18 7 SV01 SELOGIC control equation variable timer input SV1 asserted

6 SV02 SELOGIC control equation variable timer input SV2 asserted



3 SV01T SELOGIC control equation variable timer output SV1T asserted





Row Bit Definition

9.7




























Row Bit Definition

22 7 RB01 Remote bit 1 asserted

6 RB02 Remote bit 2 asserted







23 7 RB09 Remote bit 9 asserted








24 7 LT01 Latch bit 1 asserted

6 LT02 Latch bit 2 asserted















26 7 SET01 Latch bit 1 set asserted

6 SET02 Latch bit 2 set asserted








Row Bit Definition

9.8



27 7 RST01 Latch bit 1 reset asserted

6 RST02 Latch bit 2 reset asserted























30 7 SC01QU SELOGIC counter 1 up asserted

6 SC02QU SELOGIC counter 2 up asserted







31 7 SC01QD SELOGIC counter 1 down asserted

6 SC02QD SELOGIC counter 2 down asserted








Row Bit Definition

















34 7 T06_LED LED 06 asserted

6 T05_LED LED 05 asserted





1 * Not used

0 * Not used

35 7 ER1 Event report equation 1 asserted

6 ER2 Event report equation 2 asserted

5 ER3 Event report equation 3 asserted

4 FREQY Frequency Tracking asserted

3 NEWEVNT Asserts when a new event is triggered. Cleared with the TOG command

2 * Not used

1 * Not used

0 * Not used

36 7 DP01 Display point 01 asserted

6 DP02 Display point 02 asserted






Row Bit Definition

9.9













38 7 SC01R SELOGIC Counter 01, counter reset

6 SC02R SELOGIC Counter 02, counter reset







39 7 SC01LD SELOGIC Counter 01, load preset value

6 SC02LD SELOGIC Counter 02, load preset value







40 7 SC01CU SELOGIC Counter 01, count up

6 SC02CU SELOGIC Counter 02, count up







41 7 SC01CD SELOGIC Counter 01, count down

6 SC02CD SELOGIC Counter 02, count down






Row Bit Definition



42 7 SC09R SELOGIC Counter 09, counter reset








43 7 SC09LD SELOGIC Counter 09, load preset value








44 7 SC09CU SELOGIC Counter 09, count up








45 7 SC09CD SELOGIC Counter 09, count down








46 7 EQA1 VARs, A-phase, Quadrant I

6 EQA2 VARs, A-phase, Quadrant II

5 EQA3 VARs, A-phase, Quadrant III

4 EQA4 VARs, A-phase, Quadrant IV

3 EQB1 VARs, B-phase, Quadrant I

2 EQB2 VARs, B-phase, Quadrant II


Row Bit Definition

9.10



1 EQB3 VARs, B-phase, Quadrant III

0 EQB4 VARs, B-phase, Quadrant IV

47 7 EQC1 VARs, C-phase, Quadrant I

6 EQC2 VARs, C-phase, Quadrant II

5 EQC3 VARs, C-phase, Quadrant III

4 EQC4 VARs, C-phase, Quadrant IV

3 EQ3P1 VARs, 3-phase, Quadrant I

2 EQ3P2 VARs, 3-phase, Quadrant II

1 EQ3P3 VARs, 3-phase, Quadrant III

0 EQ3P4 VARs, 3-phase, Quadrant IV

48 7 PB01 Pushbutton 1 bit asserted

6 PB02 Pushbutton 2 bit asserted



3 * Not used

2 * Not used

1 * Not used

0 * Not used

49 7 T14_LED LED 14 asserted

















Row Bit Definition


























Row Bit Definition

9.11












































Row Bit Definition










































Row Bit Definition

9.12



64 7 SC17R SELOGIC counter 17 counter reset

6 SC18R SELOGIC counter 18 counter reset







65 7 SC17LD SELOGIC counter 17 load preset value

6 SC18LD SELOGIC counter 18 load preset value







66 7 SC17CU SELOGIC counter 17 count up

6 SC18CU SELOGIC counter 18 count up







67 7 SC17CD SELOGIC counter 17 count down

6 SC18CD SELOGIC counter 18 count down







68 7 SC25R SELOGIC counter 25 counter reset









Row Bit Definition

69 7 SC25LD SELOGIC counter 25 load preset value








70 7 SC25CU SELOGIC counter 25 count up








71 7 SC25CD SELOGIC counter 25 count down

























Row Bit Definition

9.13



74 7 * Not used

6 * Not used

5 * Not used

4 * Not used

3 * Not used

2 * Not used

1 * Not used

0 * Not used

75 7 * Not used

6 * Not used

5 * Not used

4 * Not used

3 * Not used

2 * Not used

1 * Not used

0 * Not used

76 7 * Not used

6 * Not used

5 * Not used

4 * Not used

3 * Not used

2 * Not used

1 * Not used

0 * Not used


Row Bit Definition

9.14


SettingsSettings Explanations

Settings ExplanationsNote that most of the settings in the settings sheets that follow include references for additional information. The following explanations are for settings that do not have reference information anywhere else in the instruction manual.

Identifier Labels The SEL-734 has two identifier labels, the Meter Identifier (MID) and the Terminal Identifier (TID). The Meter Identifier is typically used to identify the meter. Typical Terminal Identifiers include an abbreviation of the substation name and line terminal.

The meter tags each report (event report, meter report, etc.) with the Meter Identifier and Terminal Identifier. This allows you to distinguish the report as one generated for a specific location.

MID and TID settings may include the following characters: 0–9, A–Z, -, /, ., space. These two settings cannot be made via the front-panel interface.

Current Transformer Ratios

Phase and neutral current transformer ratios are set independently. If neutral channel IN is connected residually with IA, IB, and IC, then set CTR and CTRN the same. Meter settings CTR and CTRN are used in meter event reports and metering functions to scale secondary current quantities into primary values. The following interfaces are scaled into primary values: Meter Reports (MET), Human-Machine-Interface (HMI), Display Points (DP), and Distributed Network Protocol (DNP). See Appendix H: Analog Quantities for a list of all applicable analog quantities.

Potential Transformer Ratios

Meter setting PTR is the overall potential ratio from the primary system to the meter phase voltage terminals. For example, on a 480 V phase-to-phase primary system with wye-connected 277:120 V PTs, the correct PTR setting is 2.3083.

Setting PTR is used in event report and meter commands so that power system values can be reported in primary units. The following interfaces are scaled into primary values: Meter Reports (MET), Human-Machine-Interface (HMI), Display Points (DP), and Distributed Network Protocol (DNP). See Appendix H: Analog Quantities for a list of all applicable analog quantities.

Enable Settings The enable settings on Settings Sheet 1 (EDEM through EKYZ) control the settings that follow, through Sheet 16. This helps limit the number of settings that need to be made.

NOTE: When a SELOGIC control equation setting is not enabled, its equation is forced to NA and its associated Meter Word bit is forced to 0.

Each setting subgroup on Settings Sheets 1 through 16 references the controlling enable setting. For example, enable setting EKYZ controls the number of KYZ pulse bits that are available in the meter.

Other System Parameters

The global setting PHROT allows you to configure the SEL-734 to your specific system.

You can set PHROT equal to your power system phase rotation, either ABC or ACB.

Use the set DATE_F to format the date displayed in meter reports and the front-panel display. You can set DATE_F to MDY to display dates in Month/Day/Year format YMD to display dates in Year/Month/Day format, or DMY to display dates in Day/Month/Year format.

9.15


SettingsSettings Sheets

Front-Panel Settings The meter front-panel settings FP_DECPL, FP_SCALE, and FP_DND change the resolution of the front-panel display by adjusting the number of decimal places, scaling, and number of digits displayed.

Rollover Registers shown on the front panel and through the serial port will roll over when the value has reached 99,999,999 or as limited by the FP_DND setting. If a value is smaller than the maximum but not fully displayed, the FP_DECPL, FP_SCALE, and FP_DND settings may be changed to show the hidden digits.

Settings SheetsThe settings sheets that follow include the definition and input range for each setting in the meter. Refer to SELogic Pickup and Accuracies on page 1.9.

The Settings Sheets can be photocopied and filled out to set the SEL-734. Note that these sheets correspond to the serial port SET commands listed in Table 9.1.



SET.1 of 14SEL-734 Settings SheetsSET Command

Date _______________

SEL-734 Settings Sheets

SET CommandYou can access the following settings from the meter front panel and the serial port.

Identifier LabelsMeter Identifier (20 characters) MID :=

Terminal Identifier (20 characters) TID :=

Enable SettingsDemand Metering (THM = Thermal, ROL = Rolling,

BLOK = Block)EDEM :=

Predictive Demand (Y, N) (Hidden if EDEM ≠ ROL or BLOK) EPRED :=

Voltage Sag/Swell/Interruption (Y, N) ESSI :=

Transformer/Line Losses Compensation (Y, N) ETLLC :=

Transformer Copper Losses Compensation (Y, N)(Hidden if ETLLC = N)

ELCU :=

Transformer Iron Losses Compensation (Y, N)(Hidden if ETLLC = N)

ELFE :=

KYZ Pulses (N, 1–4) EKYZ :=

Current and Potential Transformer RatiosNominal Current

Current Classes CL2, CL10, CL20: 0.50 to 5.00 A secondary; Current Class 10 V LEA: 1.00 to 10.00 V secondary; Current Class options 150 V LEA and 25 V LEA: 5.00 to 100.00 LEA V secondary

INOM :=

Nominal Voltage(20–300 V for 120/240 V meters; 5–25.00 V for 25 V LEA meters, Form 9: L-N, Form 5: L-L)

VBASE :=

Phase (IA, IB, IC) Current Transformer Ratio (1.0000–6000; 1.0000–10000 for R207 and higher firmware)

CTR :=

Neutral (IN) Current Transformer Ratio (1.0000–6000; 1.0000–10000 for R207 and higher firmware)

CTRN :=

PT Ratio (1.0000–10000) PTR :=

SET.2 of 14 SEL-734 Settings SheetsSET Command


Date _______________

For the following settings, replace x with the Phase A, B (Form 9 only), or C, and replace n with the calibration point number.

Enable ITC for Current (N, 1–6) EITCI :=

Secondary Amps (Volts for LEA meters) for Calibration Point n (0.15–20 A for CL10/CL20 meters; 0.01–6.00 A for CL2 meters; 0.01–12.00 V for LEA meters)

ICAL_n :=

CT Ratio Correction Factor (0.8–1.2) IRCFx_n

CT Phase Angle Minutes (–10800 to 10800) IPAMx_n

Enable ITC for Voltage (N, 1–6) EITCV

Secondary Volts for Calibration Point n (57–132 V for 120 V meters; 100–277 V for 240 V meters)

VCAL_n

PT Ratio Correction Factor (0.8–1.2) VRCFx_n

PT Phase Angle Minutes (–10800 to 10800) VPAMx_n

Fault and Voltage Element SettingsFault Block Equation FLTBLK :=

Undervoltage Percentage Pickup (OFF, 35–140) 27P1P :=

27P1P setting percentage of Metering Voltage (120 or 240 V, see part number).

Demand Metering Settings (Make the following settings, whether preceding enable setting EDEM = THM, ROL, or BLOK)

Time constant (1, 5, 10, 15, 30, 60 minutes) DMTC :=

Sub-interval time constant (see Table 4.4)(Hidden if EDEM ≠ ROL)

DMSI :=

Demand Block Time (OFF, 1–300 min) DBLOCK :=

End of Interval Pulse Timer (OFF, 1–5 sec) EOIPT :=

Predicted Peak Demand Quantity(Hidden if EPRED = N)

PRED :=

Peak Demand Alarm Level (0.00–1,000,000.00)(Primary Units hidden if EPRED = N)

PREDAL :=

Phase pickup (OFF, 0.10–3.20 A) PDEMP :=

Neutral ground pickup—channel IN (OFF, 0.100–3.200 A) NDEMP :=

Residual ground pickup (OFF, 0.1–3.20 A) GDEMP :=

Negative-sequence pickup (OFF, 0.10–3.20 A) QDEMP :=


SET.3 of 14SEL-734 Settings SheetsSET Command

Date _______________

Transformer/Line Losses Settings(Settings dependent on preceding enable setting ETLLC = Y)

System Billing Point (1–4) BPOS :=

System Metering Point (1–4) MPOS :=

Transformer 3-Phase MVA Rating (0.00001–10000 MVA) MVA :=

Primary Line-to-Line Voltage (0.00001–10000 kV) KVLL :=

Transformer Percent Impedance (0.001–19.999%) %Z :=

Transformer Percent Exciting Current (0.001–19.999%) %IMAG :=

Transformer Copper Watt Losses (0.00001–10000 kW) LWCU :=

Transformer Iron Watt Losses (0.00001–10000 kW) LWFE :=

Supply Line Resistance (0.0000–999.9999 Ohms) SLR :=

Supply Line Reactance (0.0000–999.9999 Ohms) SLX :=

Load Line Resistance (0.0000–999.9999 Ohms) LLR :=

Load Line Reactance (0.0000–999.9999 Ohms) LLX :=

Power Transformer Turns Ratio (VSupply/VLoad) XFTR :=

Voltage Sag/Swell/Interruption Settings(Settings dependent on preceding setting ESSI = Y)

AVG_TIME (OFF, 1–10 min) AVG_TIME :=

Voltage Interruption (OFF, 5.00–99.00) VINT :=

Voltage Interruption Hysteresis (0.00–10.00) VINTHYS :=

Voltage Sag (OFF, 10.00–99.00) VSAG :=

Voltage Sag Hysteresis (0.00–10.00) VSAGHYS :=

Voltage Swell (OFF, 101.00–180.00) VSWELL :=

Voltage Swell Hysteresis (0.00–10.00) VSWELHYS :=

KYZ Pulse SettingsReplace n with a value from 1–4.

KE Scale (PRI, SEC) KEn_SCALE :=

Watthour Constant (0.0001–9,999.0000) KEn :=

KE Units (UNITY, KILO, MEGA) KEn_UNIT :=

Demand Type to Output KYZDn :=

SET.4 of 14 SEL-734 Settings SheetsSET L Command


Date _______________

KYZ Minimum Pulse Width (25, 50, 75, 100 ms) KYZPWn :=

KYZ Pulse Test Mode Settings Watthour Constant (0.0001–9999)

KET :=

Analog Output SettingsReplace n with a value from 01–04.

AOn Analog Quantity AOnAQ :=

AOn Analog Quantity Low (–2147483647.000–2147483647) AOnAQL :=

AOn Analog Quantity High (–2147483647.000–2147483647) AOnAQH :=

AOn Low Analog Output Value (±1.200 or ±24.000) AOnL :=

AOn High Analog Output Value (±1.200 or ±24.000) AOnH :=

Harmonic Trigger SettingsReplace n with a value from 02–15.

Harmonic Trigger Quantities (ALL, VOLTAGE, CURRENT) HARMTRIG :=

Include Interharmonic Quantities (Y, N) INCIHQ :=

nth Harmonic Threshold (OFF, 3–100%) HARMn :=

SELOGIC® control equation settings consist of Meter Word bits (see Table 10.6) and operators AND, OR, NOT, R_TRIG (rising edge), F_TRIG (falling edge), ( ) (parentheses), <, > (analog comparison), and = (analog equality).

Settings examples are given in Section 4: Metering–Section 9: Settings. SELOGIC control equation settings can also be set directly to 1 (logical 1) or 0 (logical 0).

Gain Adjustment SettingsWatt Gain % (–10.00 to 10.00) WGAIN :=

VAR Gain % (–10.00 to 10.00) VARGAIN :=

SET L CommandSELOGIC Control Equation Enable Settings

SELOGIC Latches (N, 1–32) ELAT :=

SELOGIC Variable (N, 1–32) ESV :=

SELOGIC Variable Timers (N, 1–32) ESVT :=

Math Variable Equations (N, 1–32) EMV :=

SELOGIC Counters (N, 1–32) ESC :=

Analog Control Values (N, 1–32) EACV :=


SET.5 of 14SEL-734 Settings SheetsSET L Command

Date _______________

Latch Bits Set/Reset Equations (see Figure 8.5)Make the following settings if preceding enable setting ELAT = 1–32. Replace n with a value from 01–32.

Set Latch Bit LTn SETn :=

Reset Latch Bit LTn RSTn :=

SELOGIC Control Equation Variable Timer Input EquationsMake the following settings if preceding enable setting ESV = 1–32. Replace n with a value from 01–32.

SELOGIC Control Equation Variable SVn SVn :=

SELOGIC Variables Timer SettingsReplace n with a value from 01–32.

SVn Timer Pickup (1000000 sec) SVnPU :=

SVn Timer Dropout (1000000 sec) SVnDO :=

Math Variable EquationsReplace n with a value from 01–32.

SELOGIC Math Equation Variable MVn MVn :=

SELOGIC Counters EquationsReplace n with a value from 01–32.

SCn Counter Preset Value, unitless (1–999999) SCnPV :=

SCn Reset (SELOGIC Equation) SCnR :=

SCn Load (SELOGIC Equation) SCnLD :=

SCn Count Up (SELOGIC Equation) SCnCU :=

SCn Count Down (SELOGIC Equation) SCnCD :=

Analog Control Value SettingsAnalog Control Value Alias (64 chars; NA to default) ACVA :=

Analog Control Value SettingsReplace n with a value from 01–32.

Analog Control Alias (64 chars; NA to default) ACVAn :=

Analog Control Value Maximum (–16777216.00 to 16777215.99)

ACVnMAX :=

Analog Control Value Minimum (–16777216.00 to 16777215.99)

ACVnMIN :=

Analog Control Value (–16777216.00 to 16777215.99) ACVn

SET.6 of 14 SEL-734 Settings SheetsSET G Command


Date _______________

Output Contact EquationsReplace n with a value from 01–04.

Output Contact OUT1n OUT1n :=

Output Contact OUT4n OUT4n :=

MIRRORED BITS® Transmit EquationsReplace n with a value from 1–8.

Channel A, transmit bit n TMBnA :=

Channel B, transmit bit n TMBnB :=

SET G CommandPower System Configuration and Date Format

Phase rotation (ABC, ACB) PHROT :=

Date format (MDY, YMD, DMY) DATE_F :=

Energy Cut-Off AngleWatt/VAR angle cut off (OFF, 1–10 degrees) ANGCUT :=

ASCII Report SettingsSEL-ASCII Decimal Places (0–3) DECPL :=

SEL-ASCII Unit Scaling (UNITY, KILO, or MEGA) SCALE :=

SEL-ASCII Display Number of Digits (5–8) DND :=

Synchronized PhasorsEnable Synchronized Phasors (Y, N) EPMU :=

Synchrophasor Time Source Type (IRIG, IEEE) TSTYPE :=

Offset from UTC (–24.00 to 24.00 hours) UTC_OFF :=

DNP Session Time Base (LOCAL, UTC) DNPSRC :=

DNP Report Time Base (LOCAL) DNPRTB :=

Optoisolated Input TimersInput IN101 debounce time (0–25 ms, 1 ms steps) IN101D :=

Input IN102 debounce time (0–25 ms, 1 ms steps) IN102D :=


SET.7 of 14SEL-734 Settings SheetsSET R Command

Date _______________

Optoisolated Input Timers for Models With Extra I/O BoardReplace n with a value from 01–04.

Input IN4n debounce time (0–25 ms, 1 ms steps) IN4nD :=

Remote Reset EquationsRemote reset equations allow remote masters to reset the SEL-734 demand or energy registers. These equations allow remote bits RB01–RB16 to reset demand, peak demand, or energy registers. Use a SELOGIC AND equation to add a remote analog quantity, RA00–RA31, as a password. See View or Reset Demand Metering Information on page 4.14 for additional details.

Reset Present Demand Value RSTDEM :=

Reset Peak Demand Value RSTPKDM :=

Reset All Energy Values RSTENGY :=

SET R CommandSequential Events Reports

Sequential Events Recorder settings consist of three trigger lists. Each trigger list can include as many as 24 Meter Word bits delimited by commas or spaces. Remove all elements from the trigger lists, or enter NA to disable sequential events recorder reports. See Sequential Events Recorder (SER) Report on page 6.8.

SER Trigger List 1 SER1 :=



Event ReportsEvent Report settings consist of three trigger lists. Each trigger list can include as many as 24 Meter Word bits created using SELOGIC equations. Remove all elements from the trigger lists or enter NA to disable Event Reports. Replace n with a value from 1–3.

ER Trigger List n ERn :=

Waveform Capture Sample Rate (1, 8 kHz) SRATE :=

Event Length (0.25, 0.5, 1.0, 2.0, 5.0, 10.0 sec) LER :=

Load Profile ReportsLoad profile settings consist of 1–12 recorders each containing up to 16 elements from Appendix H: Analog Quantities. SEL-734P models with 2 MB main boards support a maximum of four LDP recorders.

Recorder 1

Recorder 1 function (EOI, AVG, COI, MAX, MIN) LDFUNC :=

Recorder 1 list (16 elements max., enter NA to null) LDLIST :=

Recorder 1 acquisition rate (3–59 sec, 1–60 min) LDAR :=

Recorder 1 maximum duration (0.05–5000 days) LMDUR :=

SET.8 of 14 SEL-734 Settings SheetsSET F Command


Date _______________

For additional recorders, replace n with a value from 2–12.

Recorder n

Recorder n function (EOI, AVG, COI, MAX, MIN) LDFUNCn :=

Where: EOI = End of Interval, AVG = Average, COI = Change Over Interval, MAX = Maximum, MIN = Minimum

Recorder n list (16 elements max., enter NA to null) LDLISTn :=

Recorder n acquisition rate (3–59 sec, 1–60 min) LDARn :=

Recorder n maximum duration (0.05–5000 days) LMDURn :=

Fast Message SettingsFast Message Settings enable and disable Fast Messages that the SEL-734 sends after a Fast Message read request. Disable one or more Fast Messages if a communications processor indicates a memory overflow error when there are more than eight SEL-734 meters connected. If a memory overflow occurs, the SEL communications processor reports the following:

Attempting auto-configuration...FAILED, auto-configuration error

After modifying FMR1 through FMR4 in the SEL-734, auto-configure the SEL communications processor to re-configure Fast Messages available from the SEL-734.

Enable Energy Message (Y, N) FMR1 :=

Enable 4-Quadrant Demand Message (Y, N) FMR2 :=

Enable 4-Quadrant Peak Demand Message (Y, N) FMR3 :=

Enable 4-Quadrant Meter Message (Y, N) FMR4 :=

SET F CommandFront-Panel Display Settings

Front-Panel Time-out (OFF, 1–120 min) FP_TO :=

Front-Panel Contrast (1–8) FP_CONT :=

Front-Panel Decimal Places (0–4) FP_DECPL :=

Display Update Rate in seconds (1–60) SCROLD :=

Display Unit Scaling (UNITY, KILO, MEGA) FP_SCALE :=

Display Number of Digits (5–11 digits) FP_DND :=

Enable Display Points (N, 1–32) EDP :=

Front Panel LED EquationsReplace n with a value from 01–14 (T07_LED—T14_LED are only available on model 0734B)

Front Panel LED n Equation Tn_LED :=


SET.9 of 14SEL-734 Settings SheetsSET P Command

Date _______________

Display Point Labels (see Normal Front-Panel Display on page 11.2)Replace n with a value from 01–32.

Display Point n display equation DPn :=

Display if DPn = logical 1 (64 characters) DPn_1 :=

Display if DPn = logical 0 (64 characters) DPn_0 :=

SET P CommandPort Security Settings

Enable Port (Y, N) EPORT :=

All ports are available if the password jumper is installed.

Enable Telnet (Y, N) ETELNET :=

Enable Modbus (Y, N) EMODBUS :=

ETELNET and EMODBUS only apply to Ethernet ports.

Maximum Access Level (1, E, 2) MAXACC :=

Set MAXACC to the maximum access level desired for SEL or LMD Protocol. If the password jumper is installed, MAXACC does not limit the port’s access level.

Protocol Settings (See Below)Protocol

(SEL, LMD, DNP, MOD, MODM, MBA, MBB, MB8A, MB8B)

PROTO :=

Protocol Settings: Set PROTO = SEL for standard SEL ASCII protocol. For SEL Distributed Port Switch Protocol (LMD), set PROTO = LMD. Refer to Appendix B: SEL Distributed Port Switch Protocol (LMD) for details on the LMD protocol. For Distributed Network Protocol (DNP), set PROTO = DNP. Refer to Appendix E: Distributed Network Protocol for details on DNP protocol. For Modbus RTU Protocol, set PROTO = MOD; for MV-90 Protocol, set PROTO = SEL. Refer to Appendix F: Modbus RTU Communications Protocol for details on Modbus protocol. For MIRRORED BITS, set PROTO = MBA, MBB, MB8A, or MB8B. Refer to Appendix G: Mirrored Bits Communications for details on MIRRORED BITS.

The following settings are used if PROTO = LMD.

LMD Prefix (@, #, $, %, &) PREFIX :=

LMD Address (1–99) ADDR :=

LMD Settling Time (0.00–30 sec) SETTLE :=

Communications SettingsCommunications Interface (232, 485, Modem) COMMINF :=

Internal Modem Initialization AT String ATSTRING :=

Baud Rate (300, 1200, 2400, 4800, 9600, 19200, 38400, 57600, 115200)

SPEED :=

Data Bits (6, 7, 8) BITS :=

SET.10 of 14 SEL-734 Settings SheetsSET P Command


Date _______________

Parity (O, E, N) {Odd, Even, None} PARITY :=

Stop Bits (1, 2) STOP :=

Communications Settings: COMMINF is available on Port 4 only.

Set COMMINF = Modem is only available if supported by the part number.

Other Port SettingsMinutes to Port Time-out (0–30) T_OUT :=

Send Auto Messages to Port (Y, N) AUTO :=

Enable Hardware Handshaking (Y, N, MBT) RTSCTS :=

Fast Operate Enable (Y, N) FASTOP :=

Other Port Settings: Set T_OUT to the number of minutes of serial port inactivity for an automatic log out. Set T_OUT = 0 for no port time out.

Set AUTO = Y to allow automatic messages at the serial port.

Set RTSCTS = Y to enable hardware handshaking. With RTSCTS = Y, the meter will not send characters until the CTS input is asserted. Also, if the meter is unable to receive characters, it deasserts the RTS line. Setting RTSCTS is not applicable to serial Port 1 (Ethernet), Port 4A (EIA-485), or a port configured for SEL Distributed Port Switch Protocol (LMD).

Set RTSCTS = MBT is only available at 9600 baud (SPEED selection). In this mode, the meter deasserts the RTS line and does not monitor the CTS line. This selection is normally used with MIRRORED BITS, PROTO = MBA or MBB. See Appendix G: Mirrored Bits Communications for more detail.

Set FASTOP = Y to enable binary Fast Operate messages at the serial port. Set FASTOP = N to block binary Fast Operate messages. Refer to Appendix C: SEL Communications Processors for the description of the SEL-734 Meter Fast Operate commands.

Synchronized Phasor Measurements SettingsSync. Phasor Transmission Data Set (V1, V, A) PMDATA :=

Address of Sync. Phasor Measurement Data (0x–FFFFFFFFh) PMADDR :=

MIRRORED BITS Protocol SettingsReplace n with a value from 1–8.

MIRRORED BITS Transmit Identifier (1–4) TXID :=

MIRRORED BITS Receive Identifier (1–4) RXID :=

MIRRORED BITS RX Bad Pickup Time (1–10000 sec) RBADPU :=

PPM MIRRORED BITS Channel Bad Pickup (1–10000) CBADPU :=

MIRRORED BITS Receive Default State (string of 1s, 0s, or Xs)87654321

RXDFLT :=

MIRRORED BITS RMB_ Pickup Debounce Msgs (1–8) RMBnPU :=

MIRRORED BITS RMB_ Dropout Debounce Msgs (1–8) RMBnDO :=



Date _______________

DNP Protocol SettingsEnable DNP3 LAN/WAN Sessions (0–5) EDNP :=

DNP TCP and UDP Port (1–65534) DNPNUM :=

DNP Address (0–65519) DNPADR[n] :=

Master IP Address (xxx.yyy.xxx.www) DNPIP[n] :=

Transport Protocol (UDP, TCP) DNPTR[n] :=

UDP Response Port (REQ, 1–65534) DNPUDP[n] :=

DNP Address to Report to (1–65519) REPADR[n] :=

DNP Session Map (1–2) DNPMAP[n] :=

Class for Binary Event Data (0–3) ECLASSB[n] :=

Class for Counter Event Data (0–3) ECLASSC[n] :=

Class for Analog Event Data (0–3) ECLASSA[n] :=

Currents Scaling Decimal Places (0–6) DECPLA[n] :=

Voltages Scaling Decimal Places (0–6) DECPLV[n] :=

Misc Data Scaling Decimal Places (0–6) DECPLM[n] :=

Energy Counter Scaling Decimal Places (0–6) DECPLE[n] :=

Amps Reporting Deadband Counts (0–32767) ANADBA[n] :=

Volts Reporting Deadband Counts (0–32767) ANADBV[n] :=

Misc Data Reporting Deadband Counts (0–32767) ANADBM[n] :=

Minutes for Request Interval (I, M, 1–32767) TIMERQ[n] :=

Seconds to Select/Operate Time-Out (0.0–30) STIMEO[n] :=

Seconds to send Data Link Heartbeat (0–7200) DNPINA[n] :=

Data Link Retries (0–15) DRETRY :=

Seconds to Data Link Time-Out (0–5) DTIMEO :=

Event Message Confirm Timeout (1–50 sec) ETIMEO[n] :=

Class 0 Response Counter Object (20, 21, Both) CZPCT[n] :=

Enable Unsolicited Reporting (Y, N) UNSOL[n] :=

Enable Unsolicited Reporting at Power-Up (Y, N) PUNSOL[n] :=

Number of Events to Transmit On (1–200) NUMEVE[n] :=

Oldest Event to Tx On (0–99999 sec) AGEEVE[n] :=

Unsolicited Message Max Retry Attempts (2–10) URETRY[n] :=

Unsolicited Message Offline Timeout (1–5000 sec) UTIMEO[n] :=

SET.12 of 14 SEL-734 Settings SheetsSET P Command


Date _______________

Minimum Seconds from DCD to TX (0.00–1) MINDLY :=

Maximum Seconds from DCD to TX (0.00–1) MAXDLY :=

Settle Time from RTS On to TX (OFF, 0.00–30 sec) PREDLY :=

Settle Time from TX to RTS OFF (0.00–30 sec) PSTDLY :=

Modem Protocol SettingsDial Out When a New Event Is Recorded (Y, N)

(Hidden if PROTO ≠ SEL)DIALOUT :=

Event Notification String (30 chars max.) EVE_STR :=

ID Command String (20 chars max.) ID_CMD :=

Connection ID String (20 chars max.) CONN_ID :=

Modem Connected to Port (Y, N)(Show if PROTO = DNP and port is EIA-232)

MODEM :=

Modem Initialization at String (30 chars max.) ATSTRING :=

Modem Startup String (30 chars max) MSTR :=

Phone Number for Dial-Out (30 chars max) PH_NUM :=

Time to Attempt Dial (5–300 sec) MDTIME :=

Time Between Dial-Out Attempts (5–3600 sec) MDRET :=

EVE_STR, ID_CMD, and CONN_ID are available if PROTO = SEL and DIALOUT = Y.

MSTR, PH_NUM, MDTIME, and MDRET are available if PROTO = SEL and DIALOUT = Y or if PROTO = DNP and MODEM = Y. Alternatively, PH_NUM, MDTIME, and MDRET are available if the Port 4 internal modem is used and PROTO = DNP or if PROTO = SEL and DIALOUT = Y.

Modbus Protocol SettingsModbus Slave ID (1–247) SLAVEID :=

MODM Protocol Setting for MV-90Reader Password (1–247) RDRPWD :=

Ethernet Port SettingsPrimary Telnet Port (23, 1025–65534) TPORT :=

Primary Telnet Port Time-out (OFF, 1–30 min) TIDLE :=

IP Address IPADDR :=

Subnet Mask SUBNETM :=

Default Router (Gateway) DEFRTR :=



Date _______________

Table SET.1 defines the valid IP Address settings. The most significant byte (MSB) of the IP Address determines the valid range of the setting. For example, if the IP Address MSB is 192, then valid IP Addresses range from 192.0.1.1 to 192.255.254.254.

Table SET.1 Valid IP Addresses

IP Address MSBValid IP Address Range

From To

1–126 1.0.0.1 126.255.255.254

128–191 128.1.0.1 191.255.255.254

192–223 192.0.1.1 223.255.254.254



Section 10Communications

OverviewThere are various options for communicating with the SEL-734. The meter communications ports consist of the following:

➤ EIA-232

➤ EIA-485

➤ Internal Telephone Modem

➤ 10/100BASE-T Ethernet Port

➤ 100BASE-FX Fiber-Optic Ethernet Port

➤ Type 2 Optical Port

This section explains how to connect serial communications cables and how the SEL-734 uses communications protocols.

A command summary and command explanations are also included.

Communications OptionsSerial Ports Use the serial port to connect to a computer serial port for local

communications or to a modem for remote communications.

Internal Modem An optional communications card is available for the SEL-734, allowing selection of an internal telephone modem. For a list of modem-related settings and definitions, see Table 10.1. Certain modem settings are required for user-specific applications. For protocols where the meter dials out for unsolicited reporting, such as DNP, a phone number (PH_NUM), time to attempt dialing (MDTIME), and time between dial-out attempts (MDRET) settings are required.

The SEL-734 internal modem is globally compliant and allows direct connection to the Public Switched Telephone Network (PSTN). The modem includes support for CCITT V.92, V.90, V.34, V.32bis, V.32, V.22bis, V.22, V.23, V.21 Bell 212A, and Bell 103 protocols.

Table 10.1 Modem Settings (Sheet 1 of 2)

Setting Name Setting Value Description

COMMINF Modem Communications Interface Selection (232, 485, MODEM)

ATSTRING ATHX0E0&D0S0=1&K3a Modem Initialization AT String: initial-ization string used by the internal modem (up to 30 characters).

10.2


CommunicationsCommunications Options

The Modem Initialization AT String comes preset from the factory with the default string ATSTRING := ATHX0E0&D0SO = 1&K3. You may change the modem configuration by changing the AT String setting. Figure 10.1 shows the AT String expanded to better demonstrate the individual commands that make up the factory default string.

Figure 10.1 Factory Default AT String

Modem Command SetIn general, the SEL-734 modem accepts all Hayes-compatible AT commands configured by the ATSTRING setting. The following are useful AT command settings for the internal SEL-734 modem. For a full set of supported AT commands, please refer to the Multi-Tech® SocketModem® MT5600SMI Reference Guide (available from the SEL website at http://www.selinc.com/SEL-734/).

PH_NUM 15093321890b Phone Number for Dial-Out: may contain modem dial control characters (up to 30 characters).

MDTIME 60a Time to Attempt Dial: Time, in seconds, from initiating dial-out to termination due to no connection

MDRET 120a Time Between Dial-Out Attempts: Time from termination on dial-out attempt until retry dial-out

a Default SW settingb The default SW setting is blank and requires user-specific setting.

Table 10.1 Modem Settings (Sheet 2 of 2)

Setting Name Setting Value Description

ATSTRING := AT H X0 E0 &D0 S0=1 &K3

Attention CommandHang-Up Command*Basic results codes are enabledCommand characters are not echoedModem ignores DTRModem Auto-answers = 1 (answer on first ring)RTS/CTS flow control in use

*SEL recommemds that you include the Hang-up Command (H) in all AT strings entered.

Table 10.2 Useful AT Commands (Sheet 1 of 2)

Command Description

EO Disables command echo

L1 Low speaker volume (Default)

L2 Medium speaker volume

L3 High speaker volume

M0 Speaker always off

M1 Speaker on during call establishment

M2 Speaker on during answer

Sr = n Write to a S register

http://www.selinc.com/WorkArea/DownloadAsset.aspx?id=6175

http://www.selinc.com/WorkArea/DownloadAsset.aspx?id=6175

http://www.selinc.com/SEL-734/

http://www.selinc.com/SEL-734/

10.3


CommunicationsCommunications Options

FCC ComplianceThe SEL-734 optional internal modem complies with Part 68 of the FCC Rules and Regulations. The SEL-734 has a label which contains the FCC Registration Number and Ringer Equivalence Number (REN) of the modem. You must, upon request, provide this information to your telephone company. The REN is useful to determine the quantity of devices you may connect to a telephone line and still have all of these devices ring when the number is called. In most areas, the sum of the RENs of all devices connected to one line should not exceed five. To determine the number of devices you may connect to the line, contact your local telephone company to find the maximum REN for your calling area.

If your system causes harm to the telephone network, the telephone company may discontinue service temporarily. If possible, they will notify you in advance. If advance notification is not practical, you will be notified as soon as possible.

S0 = n Number of rings to auto-answer. By default n = 0.

S6 = n Wait Time Before Blind Dialing or for Dial Tone. By default n = 2.

S7 = n Wait Time for Carrier, Silence, or Dial Tone. By default n = 50.

S8 = n Pause Time for Dial Delay. By default n = 2.

S9 = n Carrier Detect Response Time. By default n = 6.

S10 = n Lost Carrier to Hang Up Delay. By default n = 14.

S11 = n DTMF Tone Duration. By default n = 95.

S30 = n Disconnect Inactivity Timer. By default n = 0.

X0 Basic response set

&D0 Ignore DTR signal

&K3 RST/CTS flow control

&P0 Pulse dial make/break ratio of 39/61 @ 10 PPS




Table 10.3 Useful Dialing Modifiers

Dial Modifiers

Description

P Select Pulse dial

T Select Tone dial

W Wait for dial tome

, Pause for duration specified in S8

! Hook flash

@ Wait for silence

Table 10.2 Useful AT Commands (Sheet 2 of 2)

Command Description

10.4


CommunicationsPort Connector and Communications Cables

Your telephone company may make changes in its facilities, equipment, operations, or procedures that could affect proper functioning of your equipment. If they do, they should notify you in advance to give you an opportunity to maintain uninterrupted telephone service.

You may not under any circumstances attempt any service, adjustments, or repairs on the modem. It must be returned to the factory for any such work.

Communications Devices

Other devices useful for communications include the SEL Communications Processors, SEL-2505 Remote I/O Module, and SEL-2100 Logic Processor. Use SEL fiber-optic transceivers (e.g., SEL-2800) to convert an EIA-232 port to a fiber-optic or Ethernet port.

PC Software You can use ACSELERATOR QuickSet® SEL-5030 Software or a variety of terminal emulation programs on your PC to communicate with the meter.

For the best display, use VT-100 terminal emulation or the closest variation.

The default settings for all serial ports are the following:

To change the port settings, use the SET P command (see Section 9: Settings).

Port Connector and Communications CablesFigure 10.2 shows the DB-9 connector pinouts for the SEL-734 serial ports.

Figure 10.2 DB-9 Connector Pinout for EIA-232 Serial Ports

Ethernet Port 1 of the meter is a standard 10/100BASE-T or 100BASE-FX Fiber-Optic Ethernet port. The default settings for the Ethernet port are the following:

➤ Primary Telnet Port: 23

➤ Primary Telnet Port Time-out: 15

➤ IP Address: 192.168.0.2

➤ Submask: 255.255.255.0

➤ Default: 192.168.0.1

The Ethernet port supports six simultaneous sessions that can include any combination of Telnet, Modbus®, or DNP3, but supports a maximum of five DNP3 LAN/WAN session.

Protocol selection for the Ethernet port is determined via the port number on which requests arrive. The protocols supported on the Ethernet port are SEL-ASCII, MODBUS/TCP, and DNP3 LAN/WAN.

The Ethernet port has two LEDs, which indicate the status of the port. Table 10.4 describes each LED. Figure 10.3 shows the location of status LEDs.

Baud Rate = 9600Data Bits = 8Parity = NStop Bits = 1

5 4 3 2 1

9 8 7 6

10.5



Figure 10.3 Ethernet Port Status LEDs

IRIG-B Two options for IRIG-B signal input are given, but only one should be used at a time. IRIG-B (01 and 02) inputs, or an SEL Communications Processor via Serial Port 3 or Port 2 may be used (see Table 10.5 and Figure 10.7). The available communications processors are the SEL-2032, SEL-2030, SEL-2020, and the SEL-2100 Logic Processor (see Table 2.2).

SEL-734 to PC The following cable diagrams show several types of EIA-232 serial communications cables that connect the SEL-734 to other devices. These and other cables are available from SEL. Contact the factory for more information.

SEL ruggedized cables, identified by an “R,” offer superior communications performance in noisy electrical environments. These cables offer additional shielding and grounding to prevent electromagnetic coupling from adjacent conductors. SEL recommends using ruggedized cable for communication lines greater than approximately 10 feet. SEL builds the following ruggedized cables compatible with the SEL-734: C234R, C287R, C227R, C280R, C222R, and C273R.

Table 10.4 Ethernet Port LED Description

LED Description

Green Port Power

Yellow Link

Green

Yellow

Table 10.5 Port Pinout Functions

Pin EIA-232 Port 3, Port 2 Port 4B EIA-485 Port 3, Port 4C

1 +5 Vdc +5 Vdc +TX

2 RXD RXD –TX

3 TXD TXD +RX

4 +IRIG-B N/C –RX

5 GND GND SHIELD

6 –IRIG-B N/C N/C

7 RTS RTS N/C

8 CTS CTS N/C

9 GND GND N/C

10.6



Figure 10.4 Cables for Connecting the SEL-734 to a Computer

SEL-734 9-Pin DTE* Device

9-Pin DTE* Device

Cable C234A/R

9-PIN MALE"D" SUB CONNECTOR

9-PIN FEMALE"D" SUB CONNECTOR

RXDTXDGNDCTS

TXDRXDGNDCTSRTSDCDDTRDSR

2 3 5 8

3 2 5 8 7 1 4 6

ORANGERED

SHIELDBLACK

SEL-734 25-Pin DTE* Device

Cable C227A/R



GNDTXDRXDGNDCTS

GNDRXDTXDGNDRTSCTSDSRDCDDTR

53298

7 3 2 1 4 5 6 8

20

BLACKRED

ORANGESHIELDWHITE

SEL-734

Cable C287/R



RXDTXDGNDRTSCTS

TXDRXDGNDCTSRTSDTRDSR

23578

3258746

ORANGERED

BLUE/SHIELDGREENWHITE

* DTE = Data Terminal Equipment (Computer, Terminal, etc.)

10.7



Figure 10.5 Cable for Connecting the SEL-734 to a DNP Device

Figure 10.6 Cable for Connecting the SEL-734 to an External Modem

SEL-734 to SEL-734,

SEL-2020, SEL-2030, SEL-2032, or SEL-2100

Figure 10.7 Cable for Connecting the SEL-734 to an SEL-2020, SEL-2030, SEL-2032, SEL-2100, or another SEL-734

SEL-734 9-Pin DNP Device

Cable C280/R



RXDTXDGNDRTSCTS

TXDRXDGNDDCDRTSCTS

23578

3 2 5 1 7 8

ORANGERED

BLUE/SHIELD

SEL-734 DCE** DEVICE

Cable C222/R



GNDTXDRTSRXDCTSGND

GNDTXD (IN)DTR (IN)RXD (OUT)CD (OUT)GND

5 3 7 2 8 9

7 2

20 3 8 1

BLACKRED

GREENORANGEWHITESHIELD

** DCE = Data Communications Equipment (Modem, etc.)

SEL-2020/2030/2032/2100 SEL-734

Cable C273A/R



RXDTXD

+IRIGGND-IRIGRTSCTS

TXDRXD+IRIGGND-IRIGCTSRTS

2 3 4 5 6 7 8

3 2 4 5 6 8 7

ORANGEREDBLUE

SHIELDBLACKGREENWHITE

10.8


CommunicationsCommunications Protocols

For long-distance communications up to 80 kilometers and for electrical isolation of communications ports, use the SEL-2800 family of fiber-optic transceivers. Contact SEL for more details on these devices.

Communications ProtocolsHardware Protocol The EIA-232 serial port supports RTS/CTS hardware handshaking. RTS/CTS

handshaking is not supported on the EIA-485 Serial Port 4A.

To enable hardware handshaking, use the SET P command to set RTSCTS = Y. Disable hardware handshaking by setting RTSCTS = N.

If RTSCTS = N, the meter permanently asserts the RTS line.

If RTSCTS = Y, the meter deasserts RTS when it is unable to receive characters.

If RTSCTS = Y, the meter does not send characters until the CTS input is asserted.

Software Protocols SEL-734 communications protocols:

➤ SEL ASCII

➤ SEL Distributed Port Switch Protocol (LMD)

➤ SEL Fast Meter

➤ SEL Compressed ASCII

➤ MV-90 Translation

➤ Modbus® RTU

➤ Modbus® TCP

➤ MIRRORED BITS® Communications

➤ Distributed Network Protocol (DNP3) (Optional)

➤ Telnet

Table 10.6 Serial Communications Port Pin/Terminal Function Definitions

Pin Function Definition

N/C No Connection

+5 Vdc (0.5 A limit) 5 Vdc Power Connection

RXD, RX Receive Data

TXD, TX Transmit Data

IRIG-B IRIG-B Time-Code Input

GND Ground

SHIELD Shielded Ground

RTS Request to Send

CTS Clear to Send

DCD Data Carrier Detect

DTR Data Terminal Ready

DSR Data Set Ready

10.9



The meter activates protocols on a per-port basis. See SET P Command on page SET.9 in the SEL-734 Settings Sheets.

SEL Fast Meter and SEL Compressed ASCII commands are active when PROTO is set to either SEL or LMD. The commands are not active when PROTO is set to DNP, Modbus, or MIRRORED BITS.

SEL ASCII ProtocolSEL ASCII protocol is designed for manual and automatic communications.

All commands received by the meter must be of the form:

<command> <Enter> or <command> <CRLF>

A command transmitted to the meter should consist of the command followed by either a CR (<Enter>) or a CRLF (carriage return and line feed).

You may truncate commands to the first three characters. For example, EVENT 1 <Enter> would become EVE 1 <Enter>. Upper- and lowercase characters may be used without distinction, except in passwords.

The meter transmits all messages in the following format:

<STX><MESSAGE LINE 1><CRLF><MESSAGE LINE 2><CRLF>

•••

<LAST MESSAGE LINE><CRLF>< ETX>

Each message begins with the start-of-transmission character (ASCII 02) and ends with the end-of-transmission character (ASCII 03). Each line of the message ends with a carriage return and line feed.

The meter implements XON/XOFF flow control.

The meter transmits XON (ASCII hex 11) and asserts the RTS output (if hardware handshaking is enabled) when the meter input buffer drops below 25 percent.

The meter transmits XOFF (ASCII hex 13) when the buffer is over 75 percent. If hardware handshaking is enabled, the meter deasserts the RTS output when the buffer is approximately 95 percent.

Automatic transmission sources should monitor for the XOFF character so they do not overwrite the buffer. Transmission should terminate at the end of the message in progress when XOFF is received and may resume when the meter sends XON.

You can use the XON/XOFF protocol to control the meter during data transmission. When the meter receives XOFF during transmission, it pauses until it receives an XON character. If there is no message in progress when the meter receives XOFF, it blocks transmission of any message presented to its buffer. Messages will be accepted after the meter receives XON.

The CAN character (ASCII hex 18) aborts a pending transmission. This is useful in terminating an unwanted transmission.

NOTE: The <Enter> key on most keyboards is configured to send the ASCII character 13 (^M) for a carriage return. This manual instructs you to press the <Enter> key after commands, which should send the proper ASCII code to the meter.

10.10



Control characters can be sent from most keyboards with the following keystrokes:

SEL Distributed Port Switch Protocol (LMD)The SEL Distributed Port Switch Protocol (LMD) permits multiple SEL meters to share a common communications channel. The protocol is selected by setting the port setting PROTO = LMD. See Appendix B: SEL Distributed Port Switch Protocol (LMD) for more information on SEL Distributed Port Switch Protocol (LMD).

SEL Fast Meter ProtocolSEL Fast Meter protocol supports binary messages to transfer metering and control messages. This protocol is described in Appendix C: SEL Communications Processors.

SEL Compressed ASCII ProtocolSEL Compressed ASCII protocol provides compressed versions of some of the meter ASCII commands. This protocol is described in Appendix C: SEL Communications Processors.

MV-90 TranslationThe meter provides MV-90 support via the Modbus map. The Modbus protocol is described in Appendix F: Modbus RTU Communications Protocol.

Modbus RTUThe meter provides Modbus RTU support. The Modbus protocol is described in Appendix F: Modbus RTU Communications Protocol.

MIRRORED BITS CommunicationsThe SEL-734 Meter supports MIRRORED BITS meter-to-meter communications on two ports simultaneously. See Appendix G: Mirrored Bits Communications.

Distributed Network Protocol (DNP3)The meter provides Distributed Network Protocol (DNP3) Level 2 Slave support. DNP is an optional protocol and is described in Appendix E: Distributed Network Protocol.

TelnetThe SEL-734 provides Telnet support via the Ethernet port (PORT 1). The meter supports a total of three simultaneous sessions on this port (see Ethernet on page 10.4).

XON: <Ctrl+Q>XOFF: <Ctrl+S>CAN: <Ctrl+X>

10.11



Ethernet Port Address Resolution Protocol

Address Resolution Protocol (ARP) packets are Ethernet packets that resolve IP addresses to MAC addresses. A gratuitous ARP is an announcement that a device broadcasts without being requested by another device.

The SEL-734 broadcasts a gratuitous ARP on power up and any time the link status changes from not linked to linked. The SEL-734 delays the broadcast by 1 second from the time the SEL-734 determines to broadcast to the actual broadcast time. For each broadcast, the SEL-734 sends four ARP packets with a 100 millisecond delay between each broadcast.

Serial Port Automatic Messages

When the serial port AUTO setting is Y, the meter sends automatic messages to indicate specific conditions. The automatic messages are described in Table 10.7.

Serial Port Access Levels

Commands can be issued to the meter via the serial port to view metering values, change meter settings, etc. The available serial port commands are listed and can be accessed only from the corresponding access level as shown in Table 10.23. The access levels are:

➤ Access Level 0 (the lowest access level)

➤ Access Level 1

➤ Access Level E

➤ Access Level 2 (the highest access level)

➤ Access Level C (use only when directed by SEL)

Again, a higher access level can access the serial port commands in a lower access level. The commands are shown in uppercase letters, but they can also be entered with lowercase letters.

Access Level 0Once serial port communications are established with the meter, the meter sends the following prompt:

=

This is referred to as Access Level 0 (see Table 10.23). Enter the ACC command at the = prompt:

=ACC <Enter>

The ACC command takes the meter to Access Level 1 (see ACC, EAC, and 2AC Commands (Go to Access Level 1, E, or 2) on page 10.14 for more detail).

Table 10.7 Serial Port Automatic Messages

Condition Description

Power Up The meter sends a message containing the present date and time, Meter and Terminal Identifiers, and the Access Level 0 prompt when the meter is turned on.

Event Trigger The meter sends an event summary each time an event report is triggered. See Section 6: Power Quality and Event Analysis.

Self-Test Warning or Failure

The meter sends a status report each time a self-test warning or failure condition is detected. See STA Command (Meter Self-Test Status) on page 10.25.

10.12



Access Level 1When the meter is in Access Level 1, the meter sends the following prompt:

=>

Commands 2AC through TRI in SEL-734 Meter Command Summary on page 10.34 are available from Access Level 1.

For example, enter the MET command at the => prompt to view metering data:

=>MET <Enter>

The 2AC command allows the meter to go to Access Level 2 (see ACC, EAC, and 2AC Commands (Go to Access Level 1, E, or 2) on page 10.14 for more detail).

Enter the 2AC command at the => prompt:

=>2AC <Enter>

The EAC command allows the meter to go to Access Level E (see ACC, EAC, and 2AC Commands (Go to Access Level 1, E, or 2) on page 10.14 for more detail).

Enter the EAC command at the => prompt:

=>EAC <Enter>

Access Level EWhen the meter is in Access Level E, the meter sends the following prompt:

E=>

Access Level 2When the meter is in Access Level 2, the meter sends the following prompt:

=>>

Commands CON through VER in Table 10.23 are available from Access Level 2.

For example, enter the SET command at the =>> prompt to make meter settings:

=>>SET <Enter>

Any of the Access Level 1 commands are also available (commands 2AC through TRI in Table 10.23) in Access Level 2.

Access Level CThe CAL access level is intended for use by the SEL factory, and for use by SEL field service personnel to help diagnose troublesome installations. A list of commands available at the CAL level is available from SEL upon request. Do not enter the CAL access level except as directed by SEL.

The CAL command allows the meter to go to Access Level C (see ACC, EAC, and 2AC Commands (Go to Access Level 1, E, or 2) on page 10.14 for more detail). Enter the CAL command at the Access Level 2 prompt:

10.13


CommunicationsCommand Summary

Command SummaryThe SEL-734 Meter Command Summary on page 10.34 lists alphabetically the serial port commands within a given access level.

Much of the information available from the serial port commands is also available via the front-panel pushbuttons. See Section 11: Front-Panel Operation for more information on the front-panel pushbuttons.

The serial port commands at the different access levels offer varying levels of control:

➤ The Access Level 1 commands allow you to look at information only (settings, metering, etc.), but not to change it.

➤ The Access Level E commands allow you to reset meter registers, including peak demand.

➤ The Access Level 2 commands allow you to change meter settings.

The meter responds with Invalid Access Level if a command is entered from an access level lower than the specified access level for the command. The following example shows how the meter responds to commands not listed above or entered incorrectly.

Invalid Command

Many of the command responses display the following header:


➤ FEEDER 1: This is the MID setting (the meter is shipped with the default setting MID = FEEDER 1; see Identifier Labels on page 9.14).

➤ STATION A: This is the TID setting (the meter is shipped with the default setting TID = STATION A; see Identifier Labels on page 9.14).

➤ Date: This is the date the command response was given (except for meter response to the EVE [Event] command, where it is the date the event occurred). You can modify the date display format by changing the DATE_F meter global setting.

➤ Time: This is the time the command response was given (except for meter response to the EVE command, where it is the time the event occurred).

➤ Time Source: This is the time source status at the time of the command response (except for the meter response to EVE command, where it is the time source status at the time the event occurred).

The serial port command explanations that follow in Command Explanations on page 10.14 are in the same order as the commands listed in Table 10.23.

10.14


CommunicationsCommand Explanations

Command ExplanationsACC, EAC, and 2AC Commands (Go to Access Level 1, E, or 2)

The ACC, EAC, and 2AC commands provide entry to the multiple access levels. Different commands are available at the different access levels as shown in Table 10.23. Commands ACC, EAC, and 2AC are explained together because they operate similarly.

➤ ACC moves from Access Level 0 to Access Level 1.

➤ EAC moves from Access Level 1 to Access Level E.

➤ 2AC moves from Access Level 1 or E to Access Level 2.

➤ CAL moves from Access Level 2 to Access Level C

Password RequirementsPasswords are required at all access levels except Access Level 0. See the PAS Command (View/Change Passwords) on page 10.31 for the list of default passwords and for more information on changing passwords.

Access Level Attempt At the Access Level 0 prompt, enter the ACC command:

=ACC <Enter>

The meter asks for the Access Level 1 password:

Password: ? @@@@@@

The meter is shipped with the default Access Level 1 password (OTTER) shown in Table 10.19. At the prompt above, enter the default password and press the <Enter> key. The meter responds:

FEEDER 1 Date: 03/05/01 Time: 08:31:10.361STATION A Time Source: ext

Level 1=>

The => prompt indicates the meter is now in Access Level 1.

If the entered password is incorrect, the meter asks for the password again (Password: ?). The meter will ask up to three times. If the requested password is incorrectly entered three times, the meter pulses the SALARM bit for one second and remains at Access Level 0 (= prompt).

The procedure to go from Access Level 1 to Access Level 2, Access Level 1 to Access Level E, Access Level E to Access Level 2, or Access Level 2 to Access Level C is much the same, with command EAC or 2AC entered at the access level screen prompt. The meter pulses the SALARM bit for one second after a successful Level 2 or Level E access. If access is denied, the SALARM bit pulses for one second.

10.15



If you are unable to enter the correct password after the third failed attempt, the SEL-734 asserts the SALARM Meter Word bit and displays the following error message on a communications terminal screen:

WARNING: ACCESS BY UNAUTHORIZED PERSONS STRICTLY PROHIBITED

Access Temporarily Denied

In addition, you cannot make further access level entry attempts for 30 seconds.

Access Level 0 Commands

BNA CommandThe BNA command produces ASCII names of all meter status bits for Fast Meter Compressed ASCII.

CAS CommandThe CAS command produces the Compressed ASCII configuration message. This configuration instructs an external computer on the method for extracting data from other Compressed ASCII commands.

DNA CommandThe DNA X command produces the ASCII names of all meter digital I/O (input/output) quantities reported in a Fast Meter message in Compressed ASCII format.

EXI CommandTerminate a current Telnet session with the EXI command. The meter will display an Invalid Command message if a Telnet session is not established.

ID CommandUse the ID command to extract meter identification codes.

SNS Command (Compressed SER Settings)The SNS command displays the SER settings in Compressed ASCII format. An SER must have been recorded in order to view this command.


CEV Command (Compressed Event Report)The CEV command displays the requested event report in 16 samples per cycle CASCII format. Use the CEV R and CEV L commands to view the requested event report in 1 kHz or 8 kHz CASCII format.

COM Command (Communications Data)The COM command displays integral meter-to-meter (MIRRORED BITS) communications data. For more information on MIRRORED BITS, see Appendix G: Mirrored Bits Communications. To get a summary report, enter the command with the channel parameter (A or B). If only one MIRRORED BITS port is enabled, the channel specifier may be omitted. Use the L parameter to get a summary report, followed by a listing of the COM records.

10.16



There may be up to 255 records in the extended report.

To limit the number of COM records displayed in the report to the 10 most recent records, type COM 10 L <Enter>.

To select lines 10 through 20 of the COM records for display in the report, type COM 10 20 L <Enter>.

COU Command (View SELOGIC Counters)The COU command displays eight SELOGIC counter values per line.

=>COU <Enter>


SC01 SC02 SC03 SC04 SC05 SC06 SC07 SC08 26568 26199 8740 10000 6444 24 1150 13

SC09 SC10 SC11 SC12 SC13 SC14 SC15 SC16 4710 19904 651 734 18424 2032 12 1150

=>

CHI Command (Compressed History)The CHI command generates an event history report in Compressed ASCII format.

CST Command (Compressed Status)The CST command generates a meter status report in Compressed ASCII format.

CTR Command (Comtrade Report)The CTR command displays the raw event report in Comtrade format. See Event Reports on page 6.2 for more information.

DAT Command (View Date)DAT displays the date stored by the internal calendar/clock in the format defined by the DATE_F Setting.

To change the date, Access Level E or higher must be obtained.

DNP Command (Show DNP Map)The DNP command is available at Access Level 1 for viewing data, but in order to re-map the DNP map, the meter must be in Access Level 2. See Configuration on page E.4 for further details on programming DNP points.

=>DNP <Enter> Binary Inputs = 81 82 83 84 85 86 87 90 91 92 93 94 95 1600 1601 1602 1603 \ 1604 1605 1606 1607 1608 1616 1617 1618 1619 1632 1633 \ 1634 1635Binary Outputs = 16 17 18 19 20 21 22Counters = 0:0Analog Inputs = 0 1 2 3 4 5 6 7 36 37 38 39 40 41 84 85 86 87 88 89 90 91 \ 92 93 94 95 104 112 113 120 121 303 304 305 306 307 308 \ 309 Analog Outputs = 0

=>

10.17



EVE Command (Event Reports)Use the EVE command to view event reports. See Section 6: Power Quality and Event Analysis for further details on retrieving event reports.

FIL DIR Command (View Settings File Directory)

=>FIL DIR <Enter>SET_ALL.TXT RCFG.TXT RERR.TXT RSET_PF.TXT RWSET_P2.TXT RWSET_P3.TXT RWSET_P4.TXT RWSET_P1.TXT RWSET_G.TXT RWSET_1.TXT RWSET_F.TXT RWSET_L.TXT RWSET_R.TXT RWSET_E.TXT RWSET_D.TXT RWSET_TOU.TXT RW

=>

FIL READ Command (Transfer Settings File)FIL READ transfers the settings files from the meter to a PC. You must use a terminal emulation program that supports manual Ymodem file transfer (e.g., HyperTerminal). Figure 10.8 shows how to save the SEL-734 front-port (SET_PF) settings file to your computer using HyperTerminal. The FIL DIR command will show a list of available files that can be saved.

In the terminal window type FIL READ SET_PF.TXT and press <Enter>. Click Transfer > Receive File and select a directory for the file. Click Receive to save the settings file from the SEL-734 to your computer. Ensure that Ymodem has been selected as the receiving protocol.

Figure 10.8 Using HyperTerminal to Read Settings

HIS Command (Event Summaries/History)HIS x displays event summaries or allows you to clear event summaries (and corresponding event reports) from nonvolatile memory.

If no parameters are specified with the HIS command:

=>HIS <Enter>

the meter displays the most recent event summaries in chronological order.

10.18



If x is a number (1–29):

=>HIS x <Enter>

the meter displays the x most recent event summaries.

If x is C, the meter clears the event summaries and all corresponding event reports from nonvolatile memory. The C parameter is only available in Access Level 2.

The event summaries include the date and time the event was triggered, the type of event, the maximum phase current in the event, the power system frequency, and the front-panel LEDs.

To display the meter event summaries, enter the following command:

=>HIS <Enter>


# DATE TIME EVENT FREQ TARGETS

10003 01/12/10 20:02:57.475 TRIG 60.00 000000110002 01/12/10 20:02:56.450 TRIG 60.00 000000110001 01/12/10 20:02:55.450 TRIG 60.00 000000110000 01/12/10 20:02:54.350 TRIG 60.00 0000001

The event type listed in the EVENT column is one of the following:

The TARGETS column will display any of the illuminated front-panel LEDs.

For more information on front-panel LEDs, see Section 8: Logic. For more information on event reports, see Section 6: Power Quality and Event Analysis.

LDP Command (Load Profile Report)Use the LDP command to view the Load Profile report. For more information on Load Profile reports, see Section 4: Metering. Access Level E or higher must be obtained to reset the Load Profile report using the LDP C command. Load Profile points must be recorded by the meter prior to executing the LDP command.

MAT CommandThe MAT command displays the results of the SELOGIC math variable equations.

=>MAT<Enter>SEL-734 Date: 01/05/02 Time: 17:20:35.051STATION A Time Source: int

MV01 MV02 MV03 MV04 MV05 MV06 204.72 127.36 3339.00 727.17 10.02 1.03

MV07 MV08 MV09 MV10 MV11 MV12 127.36 70.05 70.11 69.96 3.22 110.18

MV13 MV14 MV15 MV16 110.00 0.12 4.01 246.21

=>

ER = event report generated by assertion of SELOGIC control equation event report trigger condition setting ER

TRIG = event report generated by execution of the TRI (Trigger) command

10.19



MET CommandsThe MET commands provide access to the metering data. Metered quantities include phase voltages and currents, sequence component voltages and currents, power, frequency, energy, demand, peak demand, harmonic, crest factor, maximum/minimum logging of selected quantities, and transformer/line losses (see Table 4.2 for metered quantity definitions).

To make the extensive amount of meter information manageable, the meter divides the displayed information into seven groups:

➤ Crest Factor

➤ Demand

➤ Energy

➤ Harmonic

➤ Instantaneous Transformer/Line Losses

➤ Instantaneous and RMS

➤ Maximum/Minimum

MET CF (Crest Factor Metering)The MET CF command displays the crest factor values of the quantities in Table 10.8.

To view maximum/minimum metering values, enter the command:

=>MET CF <Enter>

Reset the maximum/minimum values using the MET CF R command from Access Level E or higher. All values will display RESET until new maximum/minimum values are recorded.

For more information on crest factor metering, see Crest Factor Metering on page 4.21.

MET D (Demand Metering)The MET D command displays the demand and peak demand values in primary units of the quantities in Table 10.9.

Table 10.8 MET CF Command Displayed Quantities


Voltages VA,B,C Wye-connected voltage inputs (kV primary)

VAB,BC,CA Delta-connected voltage inputs (kV primary)

Reset Time LAST RESET Last date and time themaximum/minimum meter was reset

Table 10.9 MET D Command Displayed Values (Sheet 1 of 2)


Power P (MWA,B,C) Single-phase megawatts (Form 9 only)

P (MW3P) Three-phase megawatts

S (MVAA,B,C) Single-phase apparent power (Form 9 only)

S (MVA3P) Three-phase apparent power

Q (MVARA,B,C) Four-quadrant single-phase megavars (Form 9 only)

Q (MVAR3P) Three-phase megavars

10.20



To view demand metering values, enter the following command:

=>MET D <Enter>

Reset the accumulated demand values using the MET R D command from Access Level 2. Reset the peak demand values using the MET R P command from Access Level E or higher. For more information on demand metering, see Demand Metering on page 4.7.

The MET D P command displays the peak demand values prior to the last MET R P command.

MET D T (Peak Demand)The MET D T command displays the values and times at which the peak demands were set.

To view the value, time, and date of peak demands, enter the following command:

=>MET D T <Enter>

The times of the peak demands are reset when the peak demands are reset using the MET R P command.

MET E (Energy Metering)The MET E command displays the quantities in Table 10.10.

To view energy metering values, enter the following command:

=>MET E <Enter>

Reset the energy values using the MET R E command from Access Level 2. For more information on energy metering, see Energy Metering on page 4.15.

Reset Time Demand, Peak Last date and time the demands and peak demands were reset

Number of Resets NUMBER OF PEAK DEMAND RESETS

Number of demand resets

Table 10.9 MET D Command Displayed Values (Sheet 2 of 2)

Table 10.10 MET E Command Displayed Quantities

Energy MWhA,B,C Single-phase megawatt hours (in and net out; Form 9 only)

MWh3P Three-phase megawatt hours (in and out)

MVAhA,B,C Single-phase mega VA hours (in and out; Form 9 only)

MVAh3P Three-phase mega VA hours (in and out)

MVARhA,B,C Single-phase megavar hours (in and out; Form 9 only)

MVARh3P Three-phase megavar hours (in and out)

kVhA,B,C Single-phase kilovolt hours (Form 9 only)

kVh3P Three-phase kilovolt hours

IhA,B,C Single-phase amp-hours

Ih3P Three-phase amp-hours

Reset Time LAST RESET Last date and time the energy meter was reset

10.21



MET FL (Flicker Metering)The MET FL command displays the following quantities:

➤ Short-Term Flicker Evaluation—PST (updated every 10 minutes)

➤ Time to next PST update

➤ Long-Term Flicker Evaluation—PLT (updated every two hours)

➤ Time to next PLT update

To view flicker metering values, enter the following command:

=> MET FL <Enter>

Reset the flicker metering values using the MET FL R command from Access Level 2.

MET H [E, O] (Harmonic Metering)The MET H command displays the following quantities:

➤ Harmonic magnitudes for each measured input quantity reported in secondary units

➤ KFACTOR for each measured phase current channel

➤ Total Harmonic Distortion per phase

➤ Distortion Power ratio

To view harmonic metering values, enter the following command:

=>MET H <Enter>

Enter E or O after the command to display Even or Odd harmonics.

MET H I [E, O] (Harmonic Magnitudes and Angles for Current)The MET H I command displays harmonic current magnitudes (in secondary units) and angles in degrees.

MET H M [E, O] (Harmonic Metering Magnitude)The MET H M command displays harmonic values as absolute magnitudes.

MET H P [E, O] (Harmonic Magnitudes for Power)The MET H P command displays harmonic power magnitudes in secondary units.

MET H V [E, O] (Harmonic Magnitudes and Angles for Voltage)The MET H V command displays harmonic voltage magnitudes in secondary units and angles in degrees.

MET H A [E, O] (Harmonic and Interharmonic Magnitudes for Voltage and Current)

The MET H A command displays harmonic and interharmonic voltage and current magnitudes in secondary units for frequencies from 20 Hz to 3285 Hz in 5 Hz bins.

MET L (Transformer/Line Loss Metering)The MET L command displays the following quantities:

➤ Supply and load line losses

➤ Transformer losses

10.22



To view energy metering values, enter the following command:

=>MET L <Enter>

MET (Instantaneous Metering)The MET command displays instantaneous fundamental magnitudes (and angles if applicable) and rms magnitudes of the quantities in Table 10.11.

Table 10.11 MET Command Displayed Magnitudes


IG Residual ground current (A primary; IG = 3I0 = IA + IB + IC)

Voltages VA,B,C Phase-to-neutral voltage inputs(kV primary; Form 9 only)

VAB,BC,CA Phase-to-phase voltages (kV primary; Form 5); Calculated phase-to-phase voltages (kV primary; Form 9)

VRMS Root-mean-square voltage

Power P (MWA,B,C) Single-phase megawatts real power (Form 9 only)

P (MW3P) Three-phase megawatts reactive power

PAVE (MWA,B,C) Single-phase megawatts averaged over one second (Form 9 only)

PAVE (MW3P) Three-phase megawatts averaged over one second

S (MVAA,B,C) Single-phase apparent power (Form 9 only)

S (MVA3P) Three-phase apparent power

U (MVAA,B,C) Single-phase vector power (Form 9 only)

U (MVA3P) Three-phase vector power

Q (MVARA,B,C) Single-phase megavars reactive power (Form 9 only)

Q (MVAR3P) Three-phase megavars reactive power

QAVE (MVARA,B,C)

Single-phase megavars averaged over one second (Form 9 only)

QAVE (MVAR3P) Three-phase megavars averaged over one second

Power Factor

PFA,B,C Single-phase power factor; leading or lagging (Form 9 only)

PF3P Three-phase power factor; leading or lagging

Sequence I1, 3I2, 3I0 Positive-, negative-, and zero-sequence currents (A primary)

V1, V2 Positive- and negative-sequence voltages (kV primary)

3V0 Zero-sequence voltage (kV primary; Form 9 voltage inputs only)

Frequency FREQ (Hz) Instantaneous power system frequency (measured on voltage channel VA or VC)

Voltage Deviation

V(%VNOM)A,B,C Phase-to-neutral percent voltage of the nominal (nameplate) voltage (%, Form 9 only)

V(%VNOM)AB,BC,

CA

Phase-to-phase percent voltage of the nominal (nameplate) voltage (%, Form 5 only)

Frequency Deviation

F(%VNOM) Instantaneous power system frequency of nominal (nameplate) frequency (%)

10.23



The angles are referenced to the A-phase voltage if it is greater than 13 V secondary; otherwise, the angles are referenced to A-phase current. The angles range from –179.99 to 180.00 degrees.

To view instantaneous metering values, enter the following command:

=>MET k <Enter>

where k is an optional parameter to specify the number of times (1–32767) to repeat the meter display. If k is not specified, the meter report is displayed once.

MET M (Maximum/Minimum Metering)The MET M command displays the maximum and minimum values of the quantities in Table 10.12.

To view maximum/minimum metering values, enter the following command:

=>MET M <Enter>

Use the MET M R command from Access Level E or higher to reset the maximum/minimum values. All values will display RESET until the SEL-734 records new maximum/minimum values.

For more information on maximum/minimum metering, see Maximum/Minimum Metering on page 4.19.

MET PM (Synchrophasors)The MET PM serial port ASCII command displays synchrophasor measurements, as Table 10.13 describes. The MET PM command operates only when EPMU = Y and the Meter Word bit TSOK := 1. The TSOK Meter Word bit indicates that the IRIG-B signal is sufficiently precise to time-stamp synchrophasor data.

The synchrophasor data are also available via the Tools > Meter & Control > Meter & Control (HMI) menu in ACSELERATOR QuickSet software.

Table 10.12 MET M Command Displayed Quantities


Voltages VA,B,C Wye-connected voltage inputs (kV primary; Form 9)

VAB,BC,CA Delta-connected voltage inputs (kV primary; Form 5)

Power P3P (MW3P) Three-phase megawatts

Q3P MVAR3P) Three-phase megavars

Reset Time LAST RESET Last date and time the maximum/minimum meter was reset

Table 10.13 MET PM Displayed Quantities

Voltages VA, VB, VC, V1 Phase-to-neutral and positive-sequence kV primary voltages, Form 9

VAB, VBC, VCA, V1 Phase-to-phase and positive-sequence kV primary voltages, Form 5

Currents IA, IB, IC, I1 Amps primary, Form 9

Frequency FREQ (Hz) Metered frequency

Digitals TSOK, SV03–SV32 Time Source OK and SELOGIC Variables

10.24



The MET PM time command directs the SEL-734 to display synchrophasor data at a specified time. For example, enter the command MET PM 14:14:12 to cause the SEL-734 to display a response (but with a time stamp of 14:14:12.000) just after 14:14:12.

To view repeating values, enter the following command:

=>MET PM k <Enter>

where k is an optional parameter to specify the number of times (1–32767) to repeat the meter display. If k is not specified, the meter report is displayed once.

QUI Command (Quit Access Level)The QUI command returns the meter to Access Level 0.

To return to Access Level 0, enter the following command:

=>QUI <Enter>

The meter sets the port access level to 0 and responds with the following:

FEEDER 1 Date: 03/05/01 Time: 08:55:33.986STATION A

=

The = prompt indicates that the meter has returned to Access Level 0.

The QUI command terminates the SEL Distributed Port Switch Protocol (LMD) connection if it is established see Appendix B: SEL Distributed Port Switch Protocol (LMD) for details on SEL Distributed Port Switch Protocol [LMD]).

SER Command (Sequential Events Recorder Report)Use the SER command to view the Sequential Events Recorder report. For more information on SER reports, see Section 6: Power Quality and Event Analysis.

SHO Command (Show/View Settings)Use the SHO command to view meter settings, SELOGIC control equations, global settings, serial port settings, sequential events recorder (SER) settings, and text label settings. Table 10.14 describes the SHO command options.

Table 10.14 SHO Command Options

Command Definition

SHO Show meter settings.

SHO L Show SELOGIC control equation settings.

SHO G Show global settings.

SHO P n Show serial port settings. n specifies the port (1, 2, 3, 4, or F);n defaults to the active port if not listed.

SHO R Show sequential events recorder (SER) settings.

SHO F Show front panel settings.

SHO E Show meter energy preload settings.

10.25



You may append a setting name to each of the commands to specify the first setting to display (e.g., SHO G displays the meter settings included in global settings). The default is the first setting.

SSI Command (Voltage Sag/Swell/Interruption Report)Use the SSI command to view the voltage sag/swell/interruption report. For more information on VSSI reports, see Section 6: Power Quality and Event Analysis.

STA Command (Meter Self-Test Status)The STA command displays the status report, showing the meter self-test information.

To view a status report, enter the following command:

=>STA n <Enter>

where n is an optional parameter to specify the number of times (1–32767) to repeat the status display. If n is not specified, the status report is displayed once.

STA Command Row and Column Definitions

The meter latches all self-test warnings and failures in order to capture transient out-of-tolerance conditions. To reset the self-test statuses, use the STA C command from Access Level 2:

=>>STA C <Enter>

The meter responds:

Reboot the meter and clear statusAre you sure (Y/N)?

Table 10.15 STA Abbreviation Definitions

Abbreviations Description

FID The firmware identifier string. It identifies the firmware revision.

CID The firmware checksum identifier.

S/N The meter’s serial number.

OS Offset—displays measured dc offset voltages in millivolts for the cur-rent and voltage channels.

PS Power Supply—displays power supply voltages in Vdc for the power supply outputs.

BATT Displays the battery voltage.

TEMP Displays the internal meter temperature in degrees Celsius.

RAM, ROM, CR_RAM(Critical RAM), and NONVOL

These tests verify the meter memory components. The columns dis-play OK if memory is functioning properly; the columns display FAIL if the memory area has failed.

CT_BRD, PT_BRD, and MISC_BRD

These tests verify the meter board components. The columns display OK if the board is functioning properly; the columns display FAIL if the board has failed.

W (Warning) or F (Failure) is appended to the values to indicate an out-of-tolerance condition.

10.26



If you select N, the meter displays:

Canceled

The meter then aborts the command.

If you select Y, the meter displays:

Rebooting the meter

The meter then restarts (just like powering down, then powering up meter), and all diagnostics are rerun before the meter is enabled. The meter must be disabled to issue the STA C command.

Refer to Table 12.5 for self-test thresholds and corrective actions.

TAR Command (Display Meter Element Status)The TAR command displays the status of front-panel target LEDs or meter elements, whether they are asserted or deasserted (see Table 10.17). The elements are represented as Meter Word bits and are listed in rows of eight, called Meter Word rows. The entire list of rows correspond to the Meter Word as described in Section 9: Settings.

A Meter Word bit is either at a logical 1 (asserted) or a logical 0 (deasserted). Meter Word bits are used in SELOGIC control equations. See Section 9: Settings and Appendix D: Setting SELogic Control Equations.

The TAR command options are shown in Table 10.16.

NOTE: The TAR R command cannot reset the latched targets if a logical 1 (asserted) condition is present.

Table 10.16 TAR Command Options

Command Description

TAR n k or TAR ROW n k

Shows Meter Word row number n (0–62). k is an optional parame-ter to specify the number of times (1–32767) to repeat the Meter Word row display. If k is not specified, the Meter Word row is dis-played once. Adding ROW to the command displays the Meter Word Row number at the start of each line.

TAR name k or TAR ROW name k

Shows Meter Word row containing Meter Word bit name (e.g., TAR 27A displays Meter Word Row 9). Valid names are shown in Table 10.17 and Table 9.3. k is an optional parameter to specify the number of times (1–32767) to repeat the Meter Word row display. If k is not specified, the Meter Word row is displayed once. Adding ROW to the command displays the Meter Word Row number at the start of each line.

TAR LIST or TAR ROW LIST

Shows all the Meter Word bits in all of the rows. Adding ROW to the command displays the Meter Word Row number at the start of each line.

TAR R Clears front-panel target LEDs. Shows Meter Word Row 0.

Table 10.17 SEL-734 Meter Word and Its Correspondence to TAR Command

TAR 0 (Front-Panel LEDs)

LED6 LED5 LED4 LED3 LED2 LED1 ENABLE

10.27



Command TAR HARM02 10 is executed in the following example:

=>TAR HARM02 10 <Enter>FALARM HARM02 HARM03 HARM04 HARM05 HARM06 HARM07 HARM080 0 0 0 0 0 0 00 0 0 0 0 0 0 00 0 0 0 0 0 0 00 0 0 0 0 0 0 00 0 0 0 0 0 0 00 0 0 0 0 0 0 00 0 0 0 0 0 0 00 0 0 0 0 0 0 0

FALARM HARM02 HARM03 HARM04 HARM05 HARM06 HARM07 HARM080 0 0 0 0 0 0 00 0 0 0 0 0 0 0

=>

Note that Meter Word row containing the HARM02 bit is repeated 10 times. In this example, the second harmonic is above the HARM02 setting (HARM02 is a logical 1). Command TAR 2 will report the same data since the HARM02 bit is in Row 1 of the Meter Word.

TIM Command (View Time)The TIM command displays the meter clock and the minutes since midnight (MINSM). To set the clock, you must be in Access Level E or higher.

TOG Command (Toggle)The TOG command resets the Meter Word bit NEWEVNT.

TRI Command (Trigger Event Report)Issue the TRI command to generate an event report:

=>TRI <Enter>Triggered

=>

If the serial port setting AUTO = Y, the meter sends the summary event report.

See Section 6: Power Quality and Event Analysis for more information on event reports.

Access Level E Commands

DAT Command (View/Change Date)To set the date, type DAT mm/dd/yy <Enter> if the DATE_F setting is MDY. If the DATE_F is set to YMD, enter DAT yy/mm/dd <Enter>. If the DATE_F is set to DMY, enter DAT dd/mm/yy <Enter>. To set the date to June 1, 2001, enter the following:

E=>DAT 6/1/01 <Enter>6/1/01E=>

You can separate the month, day, and year parameters with spaces, commas, slashes, colons, and semicolons.

NOTE: After setting the date, allow at least 60 seconds before powering down the meter or the new setting may be lost.

10.28



LDPThe load profile reports are retrieved via the LDP and LDP2–LDP12 commands, which have the following format:

LDP [a] [b]

LDP2 [a] [b]

where [a] and [b] are numeric or date parameters

The LDP and LDP2–LDP12 commands provide reports for the first and second load profile recorders, respectively. The load profile output has the following format:

=>LDP 1 <Enter>


FID=SEL-734-X238-V0-Z011010-D20080703 CID=34F6

# DATE TIME MWH3I MWH3O MVRH3I MVRH3O1 07/08/2008 09:45:00 1.576 0.000 0.604 0.000

=>

The SEL-734 places an “*” in the load profile report for any changes in date, time (including Daylight-Saving Time changes), or if TEST mode is entered during the recording interval for easy identification in the report.

If the requested load profile report rows do not exist, the meter responds:

No Load Profile Data

IRI Command (Synchronize to IRIG-B Time Code)IRI directs the meter to read the demodulated IRIG-B time code at the serial port or IRIG-B input.

To force the meter to synchronize to IRIG-B, enter the following command:

=>IRI <Enter>

If the meter successfully synchronizes to IRIG, it sends the following header and access level prompt:

FEEDER 1 Date: 03/05/01 Time: 10:15:09.609STATION A

E=>

If no IRIG-B code is present at the serial port input or if the code cannot be read successfully, the meter responds:

IRIG-B DATA ERROR

E=>

If an IRIG-B signal is present, the meter synchronizes its internal clock with IRIG-B. It is not necessary to issue the IRI command to synchronize the meter clock with IRIG-B. Use the IRI command to determine if the meter is properly reading the IRIG-B signal.

10.29



TIM Command (View/Change Time)The TIM command displays the meter clock. To set the clock, type TIM and the desired setting, then press <Enter>. Separate the hours, minutes, and seconds with colons, semicolons, spaces, commas, or slashes. To set the clock to 23:30:00, enter the following:

E=>TIM 23:30:00 <Enter>23:30:00

E=>

See Table 10.23 for a full list of Access Level E commands.


CON Command (Control Remote Bit)The CON command is a two-step command that allows you to control Meter Word bits RB01 through RB16 (see Rows 22 and 23 in Table 9.3). At the Access Level 2 prompt, type CON, a space, and the number of the remote bit you wish to control (1–16). The meter responds by repeating your command followed by a colon. At the colon, type the CON subcommand you wish to perform (see Table 10.18).

The following example shows the steps necessary to pulse Remote Bit 5 (RB05):

=>>CON 5 <Enter>

CONTROL RB5: PRB 5 <Enter>=>>

You must enter the same remote bit number in both steps in the command. If the bit numbers do not match, the meter responds with Invalid Command.

See Remote Control Switches on page 8.4 for more information.

FIL WRITE (Write Settings File)Use the FIL WRITE command to transfer settings to the meter. Figure 10.9 shows how to send front-port (SET_PF) settings from your computer to the SEL-734 using HyperTerminal.

In the terminal window type FIL WRITE SET_PF.TXT and press <Enter>. Click Transfer > Send File and select the directory that contains the settings file. Click Send to transfer the settings file from your computer to the SEL-734. Ensure that Ymodem has been selected as the receiving protocol.

FOR Command (Change Meter Form)Use the FOR command to change the form of the meter. From the Access Level 2 prompt, type FOR and press <Enter>. The meter responds by showing the present form of the meter and a prompt asking if you want to change the form.

NOTE: After setting the time, allow at least 60 seconds before powering down the meter or the new setting may be lost.

Table 10.18 SEL-734 Meter Control Subcommands

Subcommand Description

SRB n Set Remote Bit n (ON position)

CRB n Clear Remote Bit n (OFF position)

PRB n Pulse Remote Bit n for 25 ms (MOMENTARY position)

10.30



=>>FOR <Enter>The meter is currently form 5.Do you want to change it to form 9 (Y,N)?: Y<ENTER>Settings saved=>>Restarting the meter

Figure 10.9 Using HyperTerminal to Write Settings

LOO Command (Loop Back)The LOO command is used for testing the MIRRORED BITS communications channel. For more information on MIRRORED BITS, see Appendix G: Mirrored Bits Communications.

With the transmitter of the communications channel physically looped back to the receiver, the MIRRORED BITS addressing will be wrong and ROK will be deasserted. The LOO command tells the MIRRORED BITS software to temporarily expect to see its own data looped back as its input. In this mode, LBOK will assert if error-free data is received.

The LOO command with just the channel specifier, enables looped back mode on that channel for 5 minutes, while the inputs are forced to the default values.

=>>LOO A <Enter>Loopback will be enabled on Mirrored Bits channel A for the next 5 minutes.The RMB values will be forced to default values while loopback is enabledAre you sure (Y/N)?

=>>

If only one MIRRORED BITS port is enabled, the channel specifier may be omitted. To enable looped back mode for other than the 5 minute default, enter the desired number of minutes (1–5000) as a command parameter. To allow the looped back data to modify the RMB values, include the DATA parameter.

=>>LOO 10 DATA <Enter>Loopback will be enabled on Mirrored Bits channel A for the next 10 minutes.The RMB values will be allowed to change while loopback is enabled.Are you sure (Y/N)? N <Enter>Canceled.

=>>

To disable looped back mode before the selected number of minutes, re-issue the LOO command with the R parameter. If both MIRRORED BITS channels are enabled, omitting the channel specifier in the disable command will cause both channels to be disabled.

10.31



=>LOO R <Enter>Loopback is disabled on both channels.

=>>

PAS Command (View/Change Passwords)PAS allows you to inspect or change existing passwords.

The factory default passwords for Access Levels 1, E, and 2 are shown in Table 10.19.

To inspect passwords, type the following:

=>>PAS <Enter>1:OTTERE:BLONDEL2:TAIL

=>>

To change the password for Access Level 1 to Ot3579, enter the following:

=>>PAS 1 Ot3579 <Enter>Set

=>>

Similarly, PAS E and PAS 2 can be used to change the Access Level E and Access Level 2 passwords, respectively.

Passwords may include up to eight characters. The printable characters from the 7-bit ASCII set (i.e., values between 0x21 and 0x7e) are the only allowable password characters. Upper- and lowercase letters are treated as different characters. Strong passwords consist of eight characters, with at least one special character or digit and mixed case sensitivity, but do not form a name, date, acronym, or word. Passwords formed in this manner are less susceptible to password guessing and automated attacks. Examples of valid, distinct strong passwords include:

Ot3579ae A24.6852 Ihr2dcst 4u-Iwgth .734s.q

After entering new passwords, type PAS <Enter> to inspect them. Make sure they are what you intended, and record the new passwords.

If you wish to disable password protection for a specific access level, set the password to DISABLE. For example, PAS 1 DISABLE disables password protection for Level 1. The passwords can also be disabled by installing Jumper B on the main board. See Table 10.20 for password jumper location.

Table 10.19 Factory Default Passwords

Access Level Factory Default Password

1 OTTER

E BLONDEL

2 TAIL

This device is shipped with default passwords. Default passwords should be changed to private passwords at installation. Failure to change each default password to a private password may allow unauthorized access. SEL shall not be responsible for any damage resulting from unauthorized access.

! WARNING

NOTE: When accessing the meter using the front panel, you must accept the blank entry at the password prompt if passwords are disabled.

10.32



Figure 10.10 Jumper Header—Password and Breaker Jumpers

PUL Command (Pulse Output Contact)The PUL command allows you to pulse any of the output contacts for a specified length of time. The command format is shown below:

PUL x y

To pulse OUT101 for 5 seconds:

=>>PUL OUT101 5 <Enter>Are you sure (Y/N)? Y <Enter>

=>>

If the response to the Are you sure (Y/N)? prompt is N, the command is aborted.

The PUL command is supervised by the main board Breaker jumper. If the Breaker is not in place (Breaker jumper = OFF), the meter does not execute the PUL command and responds as shown below (see Table 10.20 for breaker jumper location.):

Aborted: No Breaker Jumper

The PUL command is primarily used for testing purposes.

Table 10.20 Main Board Jumpers

Jumper Default Jumper Position Function

N/A OFF N/A

N/A OFF N/A

BKR ON Breaker jumper

PWD OFF Password override

SBT OFF SELBOOT

ON BKR

OFF PWD

SBT

where:x is the output name (e.g., OUT101, OUT403) (see Figure 8.17).y is the pulse duration (1–30) in seconds. If y is not specified, the

pulse duration defaults to 1 second.

10.33



SET Command (Change Settings)The SET command allows the user to view or change the meter settings—see Table 9.1.

SET E Command (Preload Energy Values)Use the SET E command to preload energy values in the meter. Energy values are set in KILO units when using the SET E command (range 0–99,999,999,999).

STA SUse the STA S command to view all SELOGIC control equation operating errors. The STA S command only displays all SELOGIC operating errors (including Math Errors) and does not clear SELOGIC errors.

STA SC and STA SRThe STA SC and STA SR commands clear/reset the SELOGIC control equation operating errors from the status report if the errors are no longer present.

TEST MODE CommandThe TEST MODE command initiates energy tests from any rear-panel communications port. Test Mode requires meters with a front optical port. The SEL-734T and SEL-734B models do not support TEST MODE. See Using a Serial Port to Enter TEST Mode on page 12.8 for more information.

VER Command (Show Meter Configuration and Firmware Version)The VER command provides meter configuration and information such as nominal current input ratings.

Use the VER command to view the meter MAC address when needed for network configuration.

Table 10.21 STA S Command

Command Description Access Level

STA S Display detailed SELOGIC control equation error information.

2

Table 10.22 STA SC and STA SR Command

Command Description Access Level

STA SC Clear SELOGIC control equation errors. 2

STA SR Clear SELOGIC control equation errors. 2

10.34


CommunicationsSEL-734 Meter Command Summary

SEL-734 Meter Command SummaryTable 10.23 Command Summary (Sheet 1 of 3)

Access Level

Command Description

0 ACC Move to Access Level 1

0 BNA Binary names

0 CAS Compressed ASCII data configuration

0 DNA Compressed names

0 EXI Terminate a Telnet session. Only available when connected via Telnet.

0 ID Compressed ASCII Fast Meter ID

0 SNS Compressed SER settings

1 2AC Move to Access Level 2

1 CEV Compressed event report, 16 samples per cycle

1 CEV R Compressed event report, 1 or 8 kHz

1 CEV L Compressed event report, 1 or 8 kHz

1 CTR Comtrade format event

1 COM Display MIRRORED BITS channel statistics

1 COM C Reset MIRRORED BITS channel statistics

1 COU Display SELOGIC counters

1 CHI Compressed history

1 CST Compressed status

1 DAT Show date

1 DNP Show DNP map

1 EAC Move to Energy Access Level

1 EVE Event report, 16 samples per cycle

1 EVE C Compressed event report, 16 samples per cycle

1 EVE L Event report, 1 or 8 kHz

1 EVE L C Compressed event report, 1 or 8 kHz

1 EVE R Event report, 1 or 8 kHz

1 EVE R C Compressed event report, 1 or 8 kHz

1 FIL DIR List settings file directory

1 FIL READ Transfer settings file from meter

1 HIS Summary event reports

1 LDP Display report for first load profile recorder

1 LDP2–LDP12 Display report for second through twelfth load profile recorder

1 MAT Displays results of SELOGIC math variable equations

1 MET Display instantaneous metering data

1 MET CF Display crest factor metering

1 MET D Display demand metering data

1 MET D T Display peak demand times

1 MET E Display energy metering data

1 MET FL Display flicker metering quantities

10.35



1 MET H Display harmonic metering data percentages

1 MET H A Display interharmonic magnitudes

1 MET H I Display harmonic current magnitudes and angles

1 MET H M Display harmonic metering data—magnitude

1 MET H P Display harmonic power

1 MET H V Display harmonic voltage magnitudes and angles

1 MET L Display transformer/line loss data

1 MET M Display max/min metering

1 MET PM Display synchrophasor metering data

1 QUI Quit to Access Level 0

1 SER Display sequence-of-event records

1 SER C Clear sequence of event records

1 SHO Display settings

1 SHO L SELOGIC control equations

1 SHO E Preload energy values

1 SHO G Phase rotation, date format, Watt/VAR angle cutoff, synchrophasor, ASCII report scaling, and input debounce timers.

1 SHO R Events Recorder trigger conditions, Load Profile settings, and Fast Message settings.

1 SHO F Front-panel default display settings.

1 SHO P n Serial port settings for Serial Port n (n = F, 1, 2, 3, or 4).

1 SSI Display voltage sag/swell/interruption (VSSI) report

1 SSI S Display voltage sag/swell/interruption (VSSI) summary report

1 STA Display self test status

1 TAR Display Meter Word bits

1 TIM Show time

1 TOG Resets NEWEVNT Meter Word bit

1 TRI Trigger an event

E DAT Set date

E IRI Force synchronize to IRIG

E LDP C Reset first load profile recorder

E LDP2 C– LDP12 C

Reset second through twelfth load profile recorder

E MET CF R Clear crest factor metering

E MET M R Clear max/min metering

E MET P R Clear peak demand metering

E QUI Quit to Access Level 0

E TIM Set time

2 CAL Go to Access Level C

2 CON Control remote bits

2 DNP Set DNP map

2 FIL WRITE Write setting files to the meter

Table 10.23 Command Summary (Sheet 2 of 3)

Access Level

Command Description

10.36



2 FOR Change meter form

2 HIS C Clear event and history records

2 L_D Load new firmwarea

2 LOO Initiate/clear MIRRORED BITS loopback

2 MET D R Clear demand metering

2 MET E R Reset energy metering

2 PAS Set/show passwords

2 PUL Pulse output contact


2 R_S Restore factory settings

2 SET Change settings

2 SET L SELOGIC control equations

2 SET E Preset Energy values

2 SET G Phase rotation, date format, Watt/VAR angle cutoff, synchrophasor, ASCII report scaling, and input debounce timers.

2 SET R Events Recorder trigger conditions, Load Profile settings, and Fast Message settings.

2 SET F Front-panel default display settings.

2 SET P n Serial port settings for Serial Port n (n = F, 1, 2, 3, or 4).

2 SSI C Clear VSSI

2 STA S View SELOGIC control equation operating errors

2 STA S C Clear SELOGIC control equation operating errors from the status report

2 TEST MODE Display Test Mode parameters

2 VER Display version and configuration information

a When using the L_D command to upgrade from R200 to R201 firmware versions, first load R201 firmware and then R202 firmware.

Table 10.23 Command Summary (Sheet 3 of 3)

Access Level

Command Description


Section 11Front-Panel Operation

Front-Panel LayoutThe SEL-734 Meter front-panel interface consists of six programmable LEDs, an LCD display, a seven-button keypad, and an optical port connector (not applicable to SEL-734T or SEL-734B models). The front-panel layout is shown in Figure 11.1.

Figure 11.1 Meter Front Panel

LCD DisplayDisplays real time andhistoric information;

meter settings menus.

Front-PanelPushbuttons

Control the front-panel display.

ENTER Pushbutton

ConfigurableIndicator Labels

ENABLED LEDLit when the meter

is operational.

Optical Communications PortQuick access to all meter data,

control, and setting functions usinga PC, optical communications

cable, and software.

RESETPushbutton

Arrow PushbuttonsFacilitate navigation

left, right, up, and down.

11.2


Front-Panel OperationNormal Front-Panel Display

Normal Front-Panel DisplayIn normal operation, the meter ENABLED LED should be illuminated and the LCD display screen should be on. The LCD screen rotates displays showing each screen for about two seconds before moving to the next. The default rotating display screens include megawatt-hours in/out, megavar-hours in/out, three-phase power factor, and megawatts in/out. You can display messages as noted in General Operation of Rotating Display Settings on page 8.22.

Figure 11.2 Default Display Screen

If the front panel were in Access Level 2 or Access level E, it would automatically return to the default display when the display times out. See Rotating Display on page 8.22 for more information.

The display changes for the following status failure meter conditions (see Table 11.1).

The SEL-734 settings T01_LED through T06_LED control the six front-panel LEDs. These settings can be set through use of SELOGIC® control equations available in the front-panel settings (SET F command).

Front-Panel Automatic MessagesThe meter displays automatic messages under the conditions described in Table 11.1.

Front-Panel Menus and OperationsThe SEL-734 front panel gives you access to most of the information that the meter measures and stores. You can also use front-panel controls to view or modify meter settings or to reset demand values.

All of the front-panel functions are accessible through use of the seven-button keypad and LCD display. Use the keypad, shown in Figure 11.3, to maneuver within the front-panel menu structure, described in detail throughout the remainder of this section. Table 11.2 describes the function of each front-panel pushbutton.

734Meter

Table 11.1 Front-Panel Automatic Messages

Condition Front-Panel Message

Meter detecting any failure Displays the type of latest failure(see Meter Self-Tests on page 12.12)

11.3


Front-Panel OperationFront-Panel Menus and Operations

Figure 11.3 Front-Panel Pushbuttons

Front-Panel SecurityFront-Panel Access Levels

The meter front panel typically operates at Access Level 1 and allows any user to view meter measurements and settings. Some activities, such as editing settings, are restricted to those operators who know the meter Access Level 2 password.

In the figures that follow, restricted activities are marked with the padlock symbol shown in Figure 11.4.

Figure 11.4 Access Level Security Padlock Symbol

Before you can perform a front-panel menu activity that is marked in the instruction manual with the padlock symbol, you must enter the correct Access Level 2 password or Access Level E password. After you have

Table 11.2 Front-Panel Pushbutton Functions

Pushbutton Function

UP ARROW Move up within a menu or data list.

While editing a setting value, increase the value of the underlined digit.

DOWN ARROW Move down within a menu or data list.

While editing a setting value, decrease the value of the underlined digit.

LEFT ARROW Move the cursor to the left.

While viewing Event Data, move to data for a newer event.

RIGHT ARROW Move the cursor to the right.

While viewing Event Data, move to the data for an older event.

ESC Wake up the front-panel display.

Escape from the current menu or display.

ENT Move from the default display to the main menu.

Select the menu item at the cursor.

Select the displayed setting to edit the setting.

RESET Test front-panel LEDs, reset the timer when in Test mode, and assert the RESET bit.

11.4



correctly entered the Access Level 2 password, you can perform other Access Level 2 and Access Level E activities without reentering the password. The Access Level E password allows you to perform Access Level E and Access Level 1 activities.

Access Level 2 or Access Level E Password EntryWhen you try to perform an Access Level 2 or Access Level E activity, the meter determines whether you have entered the correct Access Level 2 or Access Level E password since the front-panel inactivity timer expired. If you have not, the meter displays the screen shown in Figure 11.5 for you to enter the password.

Figure 11.5 Password Entry Screen

To Enter the PasswordPerform these steps to enter the correct password to issue an Access Level 2 or Access Level E function or to change the Access Level 2 or Access Level E password, as described in Figure 11.12.

Step 1. Press the DOWN ARROW pushbutton twice. A blinking cursor will appear in the first character position of the password, and an underline will appear beneath the A character in the lower line of the display.

Step 2. Underline the first character of the password by moving through the characters shown in Figure 11.5. Use the LEFT ARROW and RIGHT ARROW pushbuttons to move the underline to the left and right and the UP ARROW and DOWN ARROW pushbuttons to move to other character rows.

Step 3. With the correct first character underlined, press the ENT pushbutton. The first character will appear in the upper line of the display, and the blinking cursor will move one character to the right.

Step 4. Using the arrow pushbuttons, continue to move within the character table and select each of the characters to build the Access Level 2 password.

Step 5. With the correct Access Level 2 password visible in the upper line of the display, use the UP ARROW and RIGHT ARROW pushbuttons to select Accept.

Step 6. Press the ENT pushbutton to accept the password shown in the upper line of the display.

If the password is correct, the meter displays the requested setting.

Password=Del Clr AcceptA B C D E F G H I J K L M N O P Q R S T U V W X Y Z . . . .a b c d e f g h i j k l m n o p q r s t u v w x y z . . . . 0 1 2 3 4 5 6 7 8 9! " # $ % ^ ' ( ) * + , - . / : ; < = > ? @ [ \ ] ^ _ ` { | } ~ . . . . . . . .

NOTE: If passwords are disabled, accept the blank entry at the password prompt.

NOTE: The factory default Access Level 2 password is TAIL.

11.5



Step 7. Press the ENT pushbutton to continue your task.

If the password is incorrect, the meter displays the message Invalid Password.

Step 8. Press the ENT pushbutton to return to your previous task.

To Correct Entry ErrorsPerform these steps to correct any password entry errors.

Step 1. If the cursor in the upper line of the display is blinking, press the ESC pushbutton once.

Step 2. Use the arrow pushbuttons to move the underline cursor to the position of the incorrect letter.

Step 3. With the incorrect letter underlined, press the DOWN ARROW pushbutton. The blinking cursor will reappear in the upper line of the display, and the underline cursor will appear in the lower line.

➢ Add New Character. To substitute a new character in the location of the blinking cursor, use the arrow pushbuttons to move the underline cursor to the location of the desired character in the character table and press the ENTER pushbutton.

➢ Delete Character. To delete the character at the blinking cursor, use the arrow pushbuttons to move the underline cursor to Del and press the ENT pushbutton.

➢ Clear Password. To clear the entire password and start over, use the arrow pushbuttons to move the underline cursor to Clr and press the ENT pushbutton.

Step 4. Continue making corrections until the password appears in the upper line of the display.

Step 5. With the correct Access Level 2 password visible in the upper line of the display, use the arrow pushbuttons to move the underline cursor to Accept.

Step 6. Press the ENT pushbutton to accept the password shown in the upper line of the display.

If the password is correct, the meter continues the task.

Step 7. Press the ENT pushbutton to continue your task. If the password was incorrect, the meter displays the message Invalid Password.

Step 8. Press the ENT pushbutton to return to your previous task.

Step 9. Repeat Step 1 through Step 8 until you enter the correct password.

11.6


Front-Panel OperationFront-Panel Main Menu

Front-Panel Main MenuAll access to information and meter settings through the front panel starts at the meter main menu. The remainder of this section describes the use of the main and lower level menus.

Main Menu

Figure 11.6 Front-Panel Main Menu

Main Menu > Meter

Figure 11.7 Main Menu > Meter Function

The METER menu includes functions to display meter data. The display function is Instantaneous. When you select a display function, such as Instantaneous in Figure 11.8, the meter displays a list of instantaneous meter values you can move through by using the UP ARROW and DOWN ARROW pushbuttons.

The other display functions operate similarly to the Instantaneous display function with the applicable values displayed.

Figure 11.8 Meter Menu > Instantaneous Meter Display Functions

Press these keysto move within the list.

Press this key to selectan underlined menu item.

LCD Display Main Menu

MAINMeterEventsTargetsStatusSet/ShowTest Mode

734MeterNOTE: The LCD display is dark if it

has timed out from inactivity. Press any key to activate the LCD display.

MAIN MeterEvents

Main Menu Item Meter Values Menu

METERInstantaneousCrest Factor



Meter Values Menu Item Instantaneous Meter Display

IA Mag= 0.00 A IA Ang= 0.00 DegIA RMS= 0.00 A • • • •Freq= 60.0 Hz


METERInstantaneousCrest Factor

11.7



Main Menu > Set/Show

Figure 11.9 Main Menu > Set/Show Function

Figure 11.10 Set/Show > Meter Function

Figure 11.11 Set Meter > Port Function

StatusSet/ShowTest Mode

Main Menu Item Set/Show Function

SET/SHOWMeter SettingsPort SettingsGlobal SettingsFront PanelDate/TimeSet PasswordPress these keys

to move within the list.


SET/SHOWMeter Settings Port Settings

Set/Show Menu Item Meter Function

METER SETTINGSMID=FEEDER1TID=STATION1EDEM=BL0K • • •HARM13=OFFHARM14=OFFHARM15=OFF

Press these keys to move within the list.

Press this key to select a settings group to set or show.

2AC

Port SettingsGlobal SettingsFront Panel Settings

Set/Show Menu Item Port Settings

PORT SETTINGS Front PortPort 1 Port 2 • • •Port 4

Press these keys to move within the list.

Press this key to select a setting to edit.

FRONT PORTPROTO=SELSPEED=9600 bps

Front Serial Port Setting Speed Setting

Baud Rate(300-38400)SPEED=9600

Press these keys to view settings choices.

Press this key to select a setting.

2AC

11.8



Figure 11.12 Set/Show > Password Function

NOTE: Edit the Access Level 2 password by using the steps described in Access Level 2 or Access Level E Password Entry on page 11.4.

Remember that the meter password is case sensitive. To disable Access Level 2 password protection, set Password = DISABLE.

NOTE: If passwords are disabled, accept the blank entry at the password prompt.

Front Panel Settings Date/TimeSet Password

Set/Show Menu Item Select Access Level to Change

SET PASSWORDEAC Password2AC Password

Press these keysto move between rows.

Press this key to select an access level.

2AC

2AC

SET PASSWORD EAC Password2AC Password

Select Access Level to Change Password Function

New EAC Pwd=Del Clr AcceptA B C D E F G H I J K L M N O P Q R S T U V W X Y Z . . . . a b c d e f g h i j k l m n o p q r s t u v w x y z . . . . 1 2 3 4 5 6 7 8 9 0! " # $ % ^ ' ( ) * + , - . / : ; < = > ? @ [ \ ] ^ _ ` { | } ~ . . . . . . . .

Press these keysto move between rows.

Press this key to select a character.

Press these keys to move between Del, Clr, Accept, and row characters.Del: Delete character(s)Clr: Clear passwordAccept: Accept password/character(s)


Section 12Testing and Troubleshooting

OverviewThis section provides guidelines for determining and establishing test routines for the SEL-734 Meter. Included are discussions on testing philosophies, methods, and tools. Meter self-tests and troubleshooting procedures are shown at the end of the section.

Testing PhilosophyRevenue and Power Quality Meter testing may be divided into three categories: acceptance, commissioning, and maintenance testing. The categories are differentiated by when they take place in the life cycle of the meter as well as by the test complexity.

The paragraphs below describe when to perform each type of test, the goals of testing at that time, and the meter functions that you need to test at each point. This information is intended as a guideline for testing SEL meters.

Acceptance Testing When: Qualifying a meter model to be used on the electrical system.

Goals:

1. Ensure meter meets published critical performance specifications, such as metering accuracy.

2. Ensure that the meter meets the requirements of the intended application.

3. Gain familiarity with meter settings and capabilities.

What to Test: All elements and logic functions critical to the intended application.

SEL performs detailed acceptance testing on all meter models and versions. The meters we ship meet their published specifications. It is important for you to perform acceptance testing on a meter if you are unfamiliar with its operating theory or settings. This helps ensure the accuracy and correctness of the meter settings when you issue them.

12.2


Testing and TroubleshootingTesting Philosophy

Commissioning Testing

When: Installing a new metering system.

Goals:

1. Ensure that all system ac and dc connections are correct.

2. Ensure that the meter functions as intended with your settings.

3. Ensure that all auxiliary equipment operates as intended.

What to Test: All connected or monitored inputs and outputs, polarity and phase rotation of ac connections.

SEL performs a complete functional check and calibration of each meter before it is shipped. This helps ensure that you receive a meter that operates correctly and accurately. Commissioning tests should verify that the meter is properly connected to the power system and all auxiliary equipment. Verify control signal inputs and outputs. Check SCADA control inputs and monitoring outputs. Use an ac connection check to verify that the meter current and voltage inputs are of the proper magnitude and phase rotation.

At commissioning time, use the METER command to verify the ac current and voltage magnitude and phase rotation. Use the PULSE command to verify meter output contact operation. Use the TARGET command to verify optoisolated input operation.

Maintenance Testing When: At regularly scheduled intervals or when there is an indication of a problem with the meter or system.

Goals:

1. Ensure that the meter is measuring ac quantities accurately.

2. Ensure that scheme logic is functioning correctly.

3. Ensure that auxiliary equipment is functioning correctly.

What to Test: Anything not shown to have operated correctly within the past maintenance interval.

SEL meters use extensive self-testing capabilities and feature detailed metering and event reporting functions that lower the dependence on routine maintenance testing.

Use the SEL meter reporting functions as maintenance tools. Periodically verify that the meter is making correct and accurate current and voltage measurements by comparing the meter output to other meter readings on that line. Using the event report current, voltage, and meter element data, you can determine that the meter elements are operating properly. Using the event report input and output data, you can determine that the meter is asserting outputs at the correct instants and that auxiliary equipment is operating properly. At the end of your maintenance interval, the only items that need testing are those that have not operated during the maintenance interval.

12.3


Testing and TroubleshootingTesting Methods and Tools

Testing Methods and ToolsTest Features Provided by the Meter

The following features shown in Table 12.1 assist you during meter testing.

TEST Mode Use the SEL-734 TEST mode to test meter functions and accuracy. TEST mode requires meters with a front optical port. The SEL-734T and SEL-734B models do not support TEST mode.

You can test the SEL-734 as you would test any digital revenue meter. The meter and test standard measure and report the same voltage, current, demand, and energy, provided you connect the meter and standard voltage elements in parallel and the current elements in series. Figure 12.1 shows an example setup of the SEL-734, test standard, and single-phase test source. Figure 12.2 shows an example setup of the SEL-734, test standard, and three-phase test source.

Table 12.1 Meter Testing Features

Command Function

METER The METER command shows the ac currents and voltages (magnitude and phase angle) presented to the meter in primary values. In addition, the command shows power system frequency (FREQ). Compare these quantities against other devices of known accuracy. The METER command is available at the serial ports and front-panel display. See Section 10: Communications and Section 11: Front-Panel Operation.

EVENT The meter generates a 15-cycle event report in response to disturbances. Each report contains current and voltage information, meter element states, and input/output contact information. If you question the meter response or your test method, use the event report for more information. The EVENT command is available at the serial ports. See Section 6: Power Quality and Event Analysis.

SER The meter provides a Sequential Events Recorder (SER) event report that time-tags changes in meter element and input/output contact states. The SER provides a convenient means to verify the pickup/dropout of any element in the meter. The SER command is available at the serial ports. See Section 6: Power Quality and Event Analysis.

TARGET Use the TARGET command to view the state of meter control inputs, meter outputs, and meter elements individually during a test. The TARGET command is available at the serial ports and the front panel. See Section 10: Communications and Section 11: Front-Panel Operation.

PULSE Use the PULSE command to test the contact output circuits. The PULSE command is available at the serial ports and the front panel. See Section 10: Communications.

KYZDT Use the KYZDT Meter Word bit to assert an output or front-panel LED to visualize the infrared test pulse from the front optical port.

12.4



Figure 12.1 Typical TEST Mode Connections for an SEL-734 Using a Single-Phase Test Source

Figure 12.2 Typical TEST Mode Connections for an SEL-734 Using Three-Phase Test Source

Use either the front panel or the serial port TEST MODE command to enter TEST mode. To enter TEST mode through the front panel, select the ENT pushbutton and use the front-panel keys to scroll to the Test Mode display. You must press the ENT pushbutton to actually enter TEST mode. Alternatively, enter TEST mode by executing the TEST MODE command on any communications port.

SEL-734Form 9

Standard

V1

E01:VA

E02:VB

E03:VC

E04:VN

V2

V1

V2

I3+

I2+

I1

I1

I2

I3

I1+

I1+

ZO5:IC+

ZO3:IB+

Z02:IA

Z04:IB

Z05:IC

Z01:IA+

Test Source

Pickup

To Ground

Optical Port(Front)

SEL-734Form 9

E01:VA

E02:VB

E03:VC

E04:VN

Z01:IA+

Z02:IA

Z03:IB+

Z04:IB

Z05:IC+

Z05:IC

V1V2

I1+

I1

I2+

I2

I3+

I3

Test Source

Standard

V1

VN

I1I1+ V2

V3

Optical Port(Front)

Pickup

To Ground

Optical Probe Cable

I2I2+I3I3+

V3

V4

12.5



TEST Mode ConsiderationsDuring TEST mode, the meter uses the optical port to transmit test pulses consistent with the register that the meter is presently displaying.

When you place the SEL-734 into TEST mode it will do the following:

➤ Stop recording Peak Demand data

➤ Stop recording Energy registers

➤ Disable communications on Port F

➤ Disable all KYZ outputs except for KYZDT

➤ Flag the next available load profile after the user exits out of Test mode.

Using TEST Mode From the Front Panel

Note that you must first exit any serial port TEST mode session in progress before you can access the SEL-734 front panel.

Entering TEST ModeTo enter TEST mode, perform the following steps:

Step 1. Press the ENT pushbutton on the front of the meter.

Step 2. Use the DOWN ARROW pushbutton five times to scroll to Test Mode.

Step 3. Enter the appropriate password.

Step 4. Press the ENT pushbutton. There will be a delay of a couple of seconds as the meter enters TEST mode.

When the meter enters TEST mode, the Meter Word bit TEST asserts.

Navigating in TEST ModeWhen you first enter TEST mode, you have the options of selecting any of the following four groups:

➤ Compensation Settings

➤ Display Energy

➤ Gain Settings

➤ Watthour Constant

To Turn Transformer/Line Losses ON or OFFStep 1. With Compensation Setting selected on the front-panel display,

press ENT.

Step 2. Use the RIGHT ARROW and LEFT ARROW pushbuttons to select Yes or No to using compensation. No is selected by default when you enter TEST mode.

Step 3. Press the ENT button.

12.6



To Adjust Gain SettingsUse the gain adjustment setting to adjust, or zero-out, any error a test standard measures. Use the WGAIN and VARGAIN to adjust Watts and VARs. For a full description of this feature, see Gain Adjustment on page 12.11.

Step 1. Use the DOWN ARROW pushbutton to select Gain Settings on the front panel display.

Step 2. Press ENT.

Step 3. Use the UP ARROW and DOWN ARROW pushbuttons to select WGAIN or VARGAIN.

Step 4. Press ENT.

Step 5. Use the RIGHT ARROW and LEFT ARROW pushbuttons to select the digit to be edited.

Step 6. Use the UP ARROW and DOWN ARROW pushbuttons to increment and decrement each digit as desired.

Step 7. When the changes to the gain setting are complete, press ENT.

Step 8. At the Save Settings? prompt, select YES to save settings or NO to abort changes and press ENT. NO is selected by default.

Step 9. If YES is selected and ENT pressed, Settings Saved will be displayed on the front-panel display. Press ENT to return to the menu.

To Initiate a TESTInitiate a test by pressing both the RESET button on the front panel of the meter and the start button on the standard simultaneously. This zeros out any energy remainder the meter may have accumulated from previous calculations.

To View a RegisterStep 1. Use the UP ARROW pushbutton to select Display Energy on the

front-panel display.

Step 2. Press ENT.

Step 3. Use the UP ARROW and DOWN ARROW pushbuttons to select the register you want.

To Use the Optical Test PulseThe optical test pulse is an energy pulse output that repeats at a predefined consumption rate. This optical pulse operates similarly to KYZ pulses, except that the optical pulse operates with rising edge pickups (see KYZ Outputs on page 8.16). The register currently displayed on the front panel determines the test pulse quantity. Select from among the following quantities:

➤ Watt-hours

➤ VAR-hours

➤ VA-hours

Select any direction (in/out, per quadrant) and phase (A, B, C, or 3) register for optical port output. The pulse weight (KET) setting for each pulse is set to a default value of 1.8 unit-hours per pulse. This results in the values shown in Table 12.2.

12.7



To Set Test Constant (KET)Step 1. From the TEST mode options display, use the DOWN ARROW

pushbutton to select Watthour Constant on the front-panel display.

Step 2. Press ENT to display the KET setting.

Step 3. Press ENT to edit the setting.

Step 4. Use the RIGHT ARROW and LEFT ARROW pushbuttons to select the digit to be edited.

Step 5. Use the UP ARROW and DOWN ARROW pushbuttons to increment and decrement each digit as necessary.

Step 6. When KET is set to the desired constant, press ENT.

Step 7. At the Save Settings? prompt, select YES to save settings or NO to abort changes and press ENT. NO is selected by default.

Step 8. If YES is selected and ENT pressed, the front-panel displays Settings Saved. Press the ESC pushbutton twice to return to the display of TEST mode options.

Exiting TEST ModeAny one of the following causes the SEL-734 to exit TEST mode:

➤ Press the ESC button on the front of the meter twice from the display of TEST mode options.

➤ TEST mode will automatically time out at a predefined point adjusted by FP_TO. Setting FP_TO to OFF will disable automatic time-out and require a manual exit from TEST mode.

➤ Power loss while in TEST mode restores normal operating conditions.

Pressing the RESET pushbutton at anytime in TEST mode does the following:

➢ Resets the FP_TO timer.

➢ Resets data accumulations to zero.

Table 12.2 Default Meter Test Pulse Weights

If the Value Displayed Is: The Test Pulse Output Is:

Watts or Watt-hours, per phase or total, in or out

Watt-hours, per phase or total, in or out, 1.8 Wh/pulse

VARs or VAR-hours, per phase or total, in or out

VAR-hours, per phase or total, in or out, 1.8 VARh/pulse

VAs or VA-hours, per phase or total, in or out

VA-hours, per phase or total, in or out, 1.8 VAh/pulse

12.8



Using a Serial Port to Enter TEST Mode

The TEST MODE command, available at Access Level 2, initiates energy tests (Watt-hour, VAR-hour pulse tests) from any communications port.

Entering TEST ModeUse a terminal emulation program (Terminal mode from ACSELERATOR QuickSet® SEL-5030 software, for example) and any rear-panel communications port to enter the TEST MODE serial port command according to the following syntax:

=>>TEST MODE<name>[TLLC]

Note that M or K prefixes in <name> are interchangeable; resulting energy value names indicate the same meter register. These prefixes do not affect scaling of TEST mode pulses, which are in units of Wh.

EXAMPLE 12.1

Entering the following:

=>>TEST MODE MW3I TLLC

causes the meter to enter TEST mode and pulse three-phase Watt-hours IN on the optical port. Transformer/line loss compensation is enabled.

Upon entering TEST mode, the meter responds as follows:

TEST MODE ACTIVEPULSING: KWH3IENERGY/PULSE: 1.8000TCCL: Enabled

Issue command TEST MODE OFF (or Ctrl-X) to exit test mode.=>>

EXAMPLE 12.2

Entering the following:

=>>TEST MODE KVRH3O

causes the meter to enter TEST mode and pulse three-phase Var-hours OUT on the optical port. Transformer/line loss compensation is disabled.

Upon entering TEST mode, the meter responds as follows:

TEST MODE ACTIVEPULSING: KVRH3OENERGY/PULSE: 1.8000TCCL: Disabled

Issue command TEST MODE OFF (or Ctrl-X) to exit test mode.=>>

where:<name> is a required parameter and can be any energy analog

quantity (excluding Vh)[TLLC] is an optional parameter that, if included, enables

transformer/line loss compensation in TEST mode

NOTE: Exit any front-panel-initiated TEST mode session prior to attempting entry for the TEST MODE command.

12.9



The SEL-734 accepts subsequent TEST MODE commands when a TEST mode session is already in progress, but only if command entry occurs at the same port that issued the original command. Enter the TEST MODE OFF command at any port to exit TEST mode.

Test Methods Test the pickup and dropout of meter elements by using one of three methods: target command indication, output contact closure, or sequential events recorder (SER).

The examples below show the settings necessary to route the first KYZ element KYZD1 to the output contacts and the SER. The KYZD1 element, like many in the SEL-734, is controlled by enable settings and/or SELOGIC® control equations. To enable the KYZD1 element, set the EKYZ enable setting to the following:

EKYZ = 1 (via the SET command)

Testing Via Front-Panel IndicatorsDisplay the state of meter elements, inputs, and outputs by using the front-panel or serial port TAR commands. Use this method to verify the pickup settings of elements.

Access the front-panel TAR command from the front-panel ENTER pushbutton menu. To display the state of the KYZD1 element on the front-panel display, press the ENTER pushbutton, cursor to the TAR option, and press ENTER. Press the UP ARROW pushbutton until TAR 12 displays on the top row of the LCD. The bottom row of the LCD displays all elements asserted in Meter Word Row 12. The meter maps the state of the elements in Meter Word Row 12 on the bottom row of LEDs. The KYZD1 element state is reflected on the left-most digit. See Table 10.17 for the correspondence between the Meter Word bits and the TAR command.

To view the KYZD1 element status from the serial port, issue the TAR KYZD1 command. The meter will display the state of all elements in the Meter Word row containing the KYZD1 element.

Review the TAR command descriptions in Section 10: Communications and Section 11: Front-Panel Operation for further details on displaying element status via the TAR commands.

Testing Via Front-Panel and Output ContactsWhen comparing front-panel energy registers and the number of KYZ output pulses, please follow the pulse schedule detailed in Table 12.3 to ensure 0.02 percent measurement accuracy per IEC 687: Output devices generally do not produce homogeneous pulse sequences. Therefore, the manufacturer shall state the necessary number of pulses to ensure a measure accuracy of at least 1/10 of the class of the meter at the different test points. Once the number of pulses exceeds the value listed in Table 12.3, the difference between the front-panel pulse outputs is negligible.

12.10



Testing Via Output ContactsYou can set the meter to operate an output contact for testing a single element. Use the SET L command (SELOGIC control equations) to set an output contact (e.g., OUT101 through OUT103 for Model 07340ES2-XX) to the element under test. The available elements are the Meter Word bits referenced in Table 9.4.

For example, to test the phase undervoltage element 27A via output contact OUT103, make the following setting:

OUT103 = 27A

Do not forget to reenter the correct meter settings when you are finished testing and ready to place the meter in service.

Testing Via Sequential Events RecorderYou can set the meter to generate an entry in the Sequential Events Recorder (SER) for testing meter elements. Use the SET R command to include the element(s) under test in any of the SER trigger lists (SER1 through SER3). See Section 6: Power Quality and Event Analysis.

To test the phase undervoltage element 27A with the SER, make the following setting:

SER1 = 27A

Element 27A asserts when phase voltage is below the pickup of the phase undervoltage element. The assertion and deassertion of the element is time stamped in the SER report. Use this method to verify timing associated with undervoltage elements, input/output operation, etc. Do not forget to reenter the correct meter settings when you are ready to place the meter in service.

Table 12.3 IEEE Recommended Test Pulses

Value of Current Recommended Number of Pulses

0.25 A 174

2.50 A 1736

5 A 3472

10 A 7944

20 A 13,889

ASSUMPTIONS

Kh 1,8 Wh/pulse

Voltage 120

Percent Error 0.02%

12.11


Testing and TroubleshootingGain Adjustment

Gain AdjustmentTo ensure that the SEL-734 meets ANSI Accuracy Class 0.2, SEL precisely calibrates each meter before it is shipped. A calibration report is included with each meter detailing the measured error over a variety of operating conditions. Some customers require the ability to adjust, or zero-out, any error measured by their test standard. The SEL-734 supports this requirement through the gain adjustment feature that scales power and energy registers shown in Table 12.4.

Use the WGAIN and VARGAIN settings to adjust Watts and VARs. These adjustments allow the user to compensate for any measured error during an accuracy test.

To determine the required gain adjustment settings, perform a Watt-hour and VAR-hour accuracy test (see Testing Methods and Tools on page 12.3). Record the results from the accuracy test and modify the WGAIN and VARGAIN settings to compensate for any error.

EXAMPLE 12.3 Set WGAIN to Compensate for a Known Accuracy Error

Step 1. TEST Mode

Follow the TEST mode instructions (TEST Mode on page 12.3) and your test standards instruction manual. Connect the ac test source, test standard, and meter as shown in Figure 12.1 or Figure 12.2.

Program the Ke into the test standard to match the KET setting of the meter. For this example we will use 1.8 Wh/pulse. Set the number of test pulses for the test standard to accumulate to 10.

10 pulses • 1.8 Wh/pulse = 18 Wh

Run the test at 2.5 Amps.

Step 2. Calculate the error.

Some test standards calculate and display the percent error for the user. If your test standard does not, it will use the Wh/pulse setting and number of pulses to determine how much energy the meter registered during the test period. This is then compared to the energy that the standard registered during the same period. These values are used to determine the percent registration of the meter.

Watt-hours registered by the meter = 18.0000 Wh

Watt-hours registered by the standard = 18.0108 Wh

The test standard is assumed to be accurate. The meter communicates that it has registered 18.0000 Wh when sending the tenth pulse to the standard. The standard has recorded 18.0108 Wh during this same period. Therefore, the meter is

Table 12.4 Values Affected by WGAIN and VARGAIN

MWA_AVG, MWB_AVG, MWC_AVG, MW3_AVG

MVRA_AVG, MVRB_AVG, MVRC_AVG, MVR3_AVG

MW(A/B/C/3)D(I/O) MVR(A/B/C/3)D(I/O)_(LD/LG)

MVR(A/B/C/3)D(I/O) MW(A/B/C/3)P(I/O)

MVR(A/B/C/3)P(I/O)_(LD/LG) MVR(A/B/C/3)P(I/O)

MWH(A/B/C/3)(I/O/_NET) MVRH(A/B/C/3)_(LD/LG)

MVRH(A/B/C/3) MW3(MX/MN)

MVR3(MX/MN) MW3CF(MX/MN)

MVR3CF(MX/MN)

12.12


Testing and TroubleshootingMeter Self-Tests

running slowly because the meter accumulated less energy than the standard. Use Equation 12.1 to calculate the percent error between the meter and the standard:

Equation 12.1

Step 3. Set the Gain Adjustment as needed.

To calculate the WGAIN setting and “zero-out” the meter to this test standard, subtract the percent error from 100 to determine the setting.

Enter this value into the WGAIN setting. This will speed the accumulation of real energy up by 0.06%.

Watt Gain %(–10.00–10) WGAIN := 0.00 ? .06

Step 4. Verify the new gain adjustment setting by testing the meter at the following points:

a. 5 amp or greater

b. .25 to .5 amps

The readings at these points should be consistent with the gain values settings. For example, if the test is performed at 2.5 amps, resulting in a +0.06% error, test at .5 amps and 5.0 amps to verify that the Watt-hour error at these points is consistent.

The VARGAIN setting is determined by the same method as the WGAIN setting.

The end user takes responsibility for applying these settings for appropriate reasons. Users are encouraged to verify that any changes to WGAIN and VARGAIN return expected results under actual metering conditions.

Meter Self-TestsThe meter runs a variety of self-tests. The meter takes the following corrective actions for out-of-tolerance conditions (see Table 12.5):

➤ HALARM Assertion: The meter asserts the HALARM bit, which can be mapped to an output contact. Alarm condition signaling can be a single five-second pulse (Pulsed) or permanent (Latched).

➤ The meter generates automatic status reports at the serial port for warnings and failures.

➤ The meter displays failure messages on the meter LCD display for failures.

Use the serial port STATUS command or front-panel STATUS command to view meter self-test status.

%ERRORWh_meter

Wh_standard--------------------------------⎝ ⎠

⎛ ⎞ 10018.000018.0108-------------------⎝ ⎠

⎛ ⎞ 100 99.94% =• =• =

100 % ERROR 100 99.94– +0.06% = =–

NOTE: The gain adjustment is not intended to calibrate the meter. It is intended to supplement the factory calibration for specific purpose(s) as deemed appropriate by the end user. If you suspect your meter is out of calibration, please contact the factory.

12.13


Testing and TroubleshootingMeter Troubleshooting

Meter TroubleshootingInspection Procedure Complete the following procedure before disturbing the meter. After you

finish the inspection, proceed to the Troubleshooting Procedure.

Step 1. Measure and record the power supply voltage at the power input terminals.

Step 2. Check to see that the power is on. Do not turn the meter off.

Step 3. Measure and record the voltage at all control inputs.

Step 4. Measure and record the state of all outputs.

Table 12.5 Meter Self-Tests

Self-Test Condition LimitsMeter

DisabledAlarm Output

Description

IA, IB, IC, IN, VA, VB, VC Offset

Warning 50 mV No Pulsed Measures the dc offset at each of the input channels every 10 seconds.

+5 V PS Failure +5.35 V +4.65 V

Yes Latched Measures the +5 V power supply every 10 seconds.

–5 V PS Failure –4.65 V–5.35 V

Yes Latched Measures the regulated –5 V power supply every 10 seconds.

+2.5 V PS Failure +2.68 V +2.32 V

Yes Latched Measures the +2.5 V power supply every 10 seconds.

+3.3 V PS Failure +3.53 V+3.07 V


+3.75 V PS Failure +4.02 V+3.48 V


–1.25 V PS Failure –1.33 V–1.16 V

Yes Latched Measures the –1.25 V power supply every 10 seconds.

BATT Warning +2.3 V No Pulse Measures the clock battery voltage.

TEMP Warning –40°C+85°C

No Measures the temperature at the A/D voltage reference every 10 seconds.

RAM Failure – Yes Latched Performs a read/write test on system RAM every 60 seconds.

ROM Failure checksum Yes Latched Performs a checksum test on the meter program memory every 10 seconds.

CR_RAM Failure checksum Yes Latched Performs a checksum test on the active copy of the meter settings every 10 seconds.

NONVOL Failure checksum Yes Latched Performs a checksum test on the nonvolatile copy of the meter settings every 10 seconds.

The following self-tests are performed by dedicated circuitry in the microprocessor and the SEL-734 main board. Failures in these tests shut down the microprocessor and are not shown in the status report.

Microprocessor Failure Yes Latched The microprocessor examines each program instruction, memory access, and interrupt. The meter displays VECTOR nn on the LCD upon detection of an invalid instruction, memory access, or spurious interrupt. The test runs continuously.

12.14


Testing and TroubleshootingMeter Troubleshooting

Troubleshooting ProcedureAll Front-Panel LEDs Dark

1. Input power not present or T3.15AH250V fuse is blown (see Power Supply Fuse Replacement on page 2.10).

2. Self-test failure.

3. Meter is in SELBOOT.

Cannot See Characters on Meter LCD Screen1. Meter is de-energized. Check to see if the HALARM contact is

closed.

2. LCD contrast is out of adjustment. Use the steps below to adjust the contrast.

a. Press the ESC pushbutton for 5 seconds.

b. The meter should turn on LCD contrast display bar.

c. Use the LEFT ARROW and RIGHT ARROW pushbuttons to adjust the contrast.

d. Press the ESC pushbutton twice to return to normal operation.

Meter Does Not Respond to Commands From Device Connected to Serial Port

1. Communications device not connected to meter.

2. Meter or communications device at incorrect baud rate or other communication parameter incompatibility, including cabling error.

3. Meter serial port has received an XOFF, halting communications. Type <Ctrl+Q> to send meter an XON and restart communications.

METER Command Does Not Respond as Expected

1. Group Settings CTR, CTRN, or PTR not set correctly.

2. Meter analog inputs not connected correctly.

Information Lost During Power Cycle

Certain functions of the SEL-734 store data in volatile memory, which is lost when the meter cycles power. The following occurs when meter power is cycled.

➤ All SELOGIC timers and math variables are lost. All values reset to zero when power is restored.

➤ Remote Bits deassert. Remote bits return to the OFF position when power is restored.

➤ Contact outputs default to their non-energized state. Outputs return to their energized state when power is restored.

➤ As much as one minute of energy register data is lost.

➤ The present peak-demand data will re-start at zero.

➤ As much as one minute of SELOGIC counter data is lost.

12.15


Testing and TroubleshootingMeter Calibration

Meter CalibrationThe SEL-734 is factory-calibrated. If you suspect that the meter is out of calibration, please contact the factory.

Factory AssistanceWe appreciate your interest in SEL products and services. If you have questions or comments, please contact us at:

Schweitzer Engineering Laboratories, Inc.2350 NE Hopkins CourtPullman, WA 99163-5603 USA Phone: +1.509.332.1890 Fax: +1.509.332.7990 Internet: www.selinc.comE-mail: [email protected]



Appendix AFirmware and Manual Versions

FirmwareDetermining the Firmware Version in Your MeterTo find the firmware version number in your SEL-734 Meter, view the status report through use of the serial port STAT command or the front-panel STATUS pushbutton.

The firmware revision number is after the R and the release date is after the D. For example, the following is firmware revision number 100, release date May 5, 2003.

FID=SEL-734-R100-V0-Z001001-D20030505

Table A.1 lists the firmware versions for R2xx/R6xx series firmware, a description of modifications, and the instruction manual date code that corresponds to firmware versions. The most recent firmware version is listed first.

Table A.2 lists the firmware versions for R1xx/R5xx series firmware, a description of modifications, and the instruction manual date code that corresponds to firmware versions. The most recent firmware version is listed first.

Table A.1 Firmware Revision History for R2xx/R6xx Series—S/N 2009315xxx and Later (Sheet 1 of 3)

Firmware Identification (FID) Number Summary of RevisionsManual

Date Code

Form 5 and 9 MeterSEL-734-R212-V0-Z106104-D20130118

➤ Increased the number of available SELOGIC control equations to 32.

➤ Applied ANGCUT setting to fundamental-only power values.

➤ Added support for an analog input card.

➤ Added 32 SELOGIC Analog Control Value elements.

➤ Added fundamental-only power values to SELogic control equations.

➤ Synchronized the energy quantity update rate with the LDP acquisition rate.

20130118


➤ Corrected issue with Report Class settings when upgrading firmware to R210.

20120823


➤ Corrected issue with sending design templates to the meter at 9600 baud.

➤ Added UTC offset functionality to time synchronizations from the DNP server.

➤ Modified the DNP per-point scaling range.

➤ Modified DNP unsolicited reporting on power up. Now the meter sends an unsolicited DNP message when turned on.

➤ Corrected issue with power factor reporting. Power factor reported via Modbus had a small rounding error.

➤ Corrected issue with incorrectly applied ITC correction factors.

➤ Corrected three-phase apparent power reporting.

➤ Added INOM setting. Now VSSI reports the neutral current as a percentage of the INOM setting.

➤ Changed the 27P element functionality. Now the 27P elements use the VBASE setting as the base voltage.

➤ Added new LEA option to SEL-734B.

➤ Corrected issue with incorrect phase-to-phase voltages reported in SELOGIC control equations. Applies to 240 V meters.

20120521

A.2


Firmware and Manual VersionsFirmware


➤ Corrected an accuracy issue with Form 5 meters when the voltages are applied single-phase.

20120306


➤ Corrected issue with the neutral current (IN) reporting 0. 20120215


➤ Added Instrument Transformer Compensation.

➤ Modified CTR setting range.

20120119


➤ Corrected flow control handling on Ethernet communications.

➤ Changed three-phase energy calculation. Addresses three-phase energy accumulation when power flows in opposite directions on different phases.

➤ Corrected an issue in DNP where saving settings or disconnecting and reconnecting a DNP/IP session could cause the meter to return a response with all zero values.

20111216


➤ Manual update only—see Table A.3 for a summary of manual changes.

20110719


➤ Added more Subnet Mask combinations.

➤ Changed the device display to show the peak demand’s date and time on the same row of the LCD.

➤ Improved the IEC 61000-4-15 flicker accuracy.

➤ Resolved the issue with Port 3 when configured for EIA-485 and DNP.

➤ Resolved the issue with Load Profile’s File Read command and cor-rupted records.

20110426


➤ Added port security settings EPORT, ETELNET, EMODBUS, and MAXACC.

➤ Added support for a total of five DNP sessions over any combination of serial, EIA-485, TCP/IP, and modem communications. A total of six communications sessions are available on the Ethernet port.

➤ Added NET Energy metering to Analog Quantities and DNP map.

➤ Added Frozen and Consumed Energy energy values to Analog Quan-tities and DNP map.

➤ Added True Power Factor to Analog Quantities and DNP map.

➤ Added Monthly and Consumed Energy Values to Analog Quantities and DNP map.

➤ Added support for a neutral current channel for meters with LEA current inputs.

➤ Added most recent LDP records of all LDP recorders to DNP map.

➤ Fixed issue with compressed ASCII communications.

20101008


➤ Corrected CAS command response to ensure compatibility with SEL communications processors.

➤ Improved GPSB diagnostic response.

20100817


➤ Support four auxiliary pushbuttons and eight additional LEDs.

➤ Support EIA-232 ordering option for the front panel (Port F).

➤ Support an ordering option with no front-panel display, pushbuttons, LEDs, or communications port.

➤ Support an ordering option for 0–10 Vac low energy analog (LEA) inputs.

➤ Corrected issue with sending 4–20 mA settings to the meter from ACSELERATOR® QuickSet.

➤ Corrected issue with time loss when no power is applied to the meter.

➤ Corrected behavior of dynamic VBASE when PTR is not set to 1.

➤ Corrected the value reported for power factor in TOU when TLLC is enabled.

➤ Modified SELOGIC counter reset behavior on settings change.

20100519



Date Code

A.3




➤ Added FORm command to change between form 5 and 9.

➤ Added interharmonic measurements in 5 Hz bins.

➤ Added THDG (Grouped Total Harmonic Distortion).

➤ Added harmonic graphing in QuickSet HMI.

➤ Changed VSSI processing for adaptive VBASE

➤ Added new setting AVG_TIME.

➤ Added event report lengths of 2, 5, and 10 seconds.

➤ Added binary COMTRADE Format Event Reports.

➤ Decreased event retrieval time.

➤ Added support for two-wire DNP applications.

➤ SELOGIC counters are now nonvolatile.

➤ Added settings to select 232, 485, or Modem on Port 4 (no jumper required).

➤ Added support for 4–20 mA analog outputs.

➤ Added support for future main board communications options.

➤ Added support for baud rates up to 115200.

➤ Added amp-hour to analog values, DNP, and Modbus.

➤ Added QuickSet HMI MV-90 Engineering Units report.

➤ Added CSV export for SER data.

➤ Counters and Math now available in QuickSet HMI.

➤ Added Password interface in QuickSet HMI Control Window.

20100326

Form 5 MeterSEL-734-R600-V0-Z100100-D20091019


➤ Added support for 32 MB and 128 MB memory options.

➤ Increased Ethernet throughput.

➤ Revised firmware for processor update (supports meters built after 20090315xxx).

20091019



Date Code

Table A.2 Firmware Revision History for R1xx/R5xx Series—S/N 2009314xxx and Earlier (Sheet 1 of 7)


Date Code



➤ Corrected a case where polling via DNP/IP could disable the meter. 2011114



➤ Changed three-phase energy calculation. Addresses three-phase energy accumulation when power flows in opposite directions on different phases.

20120119




20110719



➤ Added Port Security settings.

➤ Added more Subnet Mask combinations.

➤ Resolved the issue with Load Profile’s File Read command and cor-rupted records.

20110426



➤ Corrected the value reported for power factor in TOU when TLLC is enabled.

20101008

A.4





➤ Reduced the possibility of an VSSI overflow (indicated by an “X” in the SSI report).

➤ Improved light-load calibration for meters upgraded from R119/R519 through R129/R529 to R130/R530 or higher.

➤ Corrected DST initialization for meters upgraded to R126 or higher with TOU disabled.

➤ Improved firmware upgrade from R126 and lower to preserve data representation in SEL ASCII and DNP.

20091112



➤ Corrected issue with reading event reports generated under firmware versions prior to R131/R531.

20090730



➤ Added creation of LDP records when in test mode.

➤ Added meter's serial number to the STA and VER reports.

➤ Added support in upgrade software to enter the meter’s serial number.

➤ Improved accuracy of VSSI reported duration and magnitude.

➤ Added one decimal place to VSSI report.

➤ Changed VDEV and FDEV naming convention in MET report to V(%VNOM) and F(%FNOM) to better represent the values.

➤ Added additional information to STA report.

➤ Added CZPCT setting to configure Class 0 DNP polling.

➤ Added flagging of PST and PLT values in MET FL report when the channel voltage is not within 20% of VBASE setting.

➤ Corrected L-L quantities in analog output card and SELOGIC.

➤ Corrected diagnostic routine reporting a false positive ROM failure.

➤ Corrected behavior of DNP binary inputs for certain user map con-figurations.

20090717



➤ Supports up to 12 load profile recorders with up to 16 channels each.

➤ Added load profile channel integration functions including min, max, average, and change over interval.

➤ Added VSSI summary with start time, duration, depth, and ITIC/CBEMA Meter Word bits.

➤ Added ITIC/CBEMA curve in ACSELERATOR QuickSet® SEL-5030 Software.

➤ Added voltage and current imbalance and average quantities.

➤ Improved Test Mode performance to reduce testing time.

➤ Improved Harmonic accuracy.

➤ ACSELERATOR QuickSet HMI Test Mode now operates over the meter's front optical port and supports changing the KET.

➤ Added math variables and SELOGIC counters to load profile and dis-play points.

➤ Added support for DMY date format.

➤ Added Meter Word bits for Time of Use season change (SESNCH) and rate change (RATECH).Added Meter Word bits for day-light-saving change (DSTCH), setting change (SETCHG), and low clock battery (LOWBAT).

➤ Removed unused Meter Word bits DOWCH, HOLCH, ALT1CH, ALT2CH, and SLFRD. Note that if DOWCH was included in any equations it will now function as DSTCH. All others will evaluate to zero.

➤ Corrected issue with load profile file read.

➤ Corrected crest factor calculations for 240 V meters.

➤ Corrected issue with CEV reports when power system is off-nominal.

20090421



Date Code

A.5





➤ Corrected issue with firmware upgrades where user settings could be lost.

➤ Corrected issue with LDP timestamp when IRIG is connected.

➤ Improved response time of contact inputs when ac is applied.

20090319



➤ Added support for DNP3 LAN/WAN.

➤ Added a second independent user map for DNP.

➤ Improved communications reliability of DNP with an updated library.

➤ Improved the MV-90 communications interface for faster read times and to maintain engineering access.

➤ Added FILE READ and FILE SHOW support for LDP data.

➤ Changed port PROTO setting option from MV-90 to MODM (Modbus over Modem).

➤ Added HHF and CSV file export capability.

➤ Added VSSI and LDP graphing capability.

➤ Allow demand, peak demand, and energy reset through DNP.

➤ Support math variables in Display Points.

➤ Added 3 dedicated settings for improved front-panel & serial port scaling.

➤ LDP data retrieved via LDP command and DNP now in secondary quantities to match Modbus.

➤ LDP records are no longer affected by a change in CTR or PTR.

➤ Improved Ethernet communications with 10/100MB autonegotiate.

➤ Improved accuracy of demand calculated from energy consumed in LDP interval.

➤ Corrected behavior of TOU demand values when aliased in Display Points.

20090108



➤ Added IEC 61000-4-15 Flicker.

➤ Added magnitudes, angles, and active power to the 50th harmonic. Accuracy compliant with IEC 61000-4-7.

➤ Added a second load profile recorder.

➤ Enhanced event reporting capabilities.

➤ Increased memory for load profile and event reporting.

➤ Modified ID and VER commands to reflect increased memory.

➤ Added modem dial-out on event trigger.

➤ Added voltage and frequency deviation quantities.

➤ Added VSSI to DNP.

➤ Increased number of TOU self reads from 6 to 15.

➤ Added daily repeating functions for TOU.

➤ Modified DNP and Modbus to include new quantities.

➤ Corrected communications issue with SUBNET Solutions® SSNET software when SER settings contain a 0 or NA.

20080805



➤ Added support for a Class 2 CT card.

➤ Improved Load Profile Data recording when adjusting time across one interval boundary.

➤ Corrected IG stability in the VSSI report.

20080313



➤ Improved reliability of DNP communications over Port 2 and Port F.

➤ Corrected timestamps on LDP records to improve MV-90 reads.

20071207



Date Code

A.6





➤ Prevented possibility of meter disabling when modifying Port 4 settings. 20071019



➤ Enhanced Synchrophasor performance.

➤ Corrected Device Time Synchronization via DNP.

➤ Corrected potential Peak Demand discrepancy between Load Profile and Time-of-Use.

➤ Corrected issue with Load Profile lookup via Modbus/MV-90 protocol.

➤ Corrected potential MV-90 protocol lockout.

➤ Added ability to enable/disable certain Fast Messages.

20070920



➤ Added Load Profile data to DNP.

➤ Expanded LDAR setting range to include 1-minute Load Profile acquisition rate.

➤ Expanded DMTC setting range to include a 1-minute demand time constant.

➤ Reordered Test Mode quantities to make MWH3I the default test quantity.

➤ Corrected Time-of-Use processing when time is changed or IRIG-B is connected.

➤ Corrected per-point scaling on DNP counters.

➤ Corrected Load Profile DST flag when the Meter loses power.

➤ Corrected Modbus and MV-90 SER number reporting when SER > 512 records.

20070521



➤ Added support for new analog output, digital output card.

➤ Added Remote Analogs to SELOGIC for support of analog outputs.

➤ Added Analog Output Objects, 40 and 41, to DNP for support of Remote Analogs.

➤ Added TEST MODE command to ACSELERATOR QuickSet and SEL ASCII protocol.

➤ Corrected front-panel default labels for VARh and VAh.

➤ Added ESPH setting to enable/disable synchrophasors.

➤ Changed VSSI, LDP, and SER reports to indicate invalid data for records with a checksum error.

➤ Changed flagging for time/date changes in load profile when IRIG-B is used.

➤ Changed ACSELERATOR QuickSet support to disallow a setting of NA for FLTBLK.

➤ Added ACSELERATOR QuickSet support for DNP External Modem Settings on Port 2.

➤ Adjusted LDP report column spacing to accommodate more digits.

➤ Modified SER to report Daylight-Saving Time changes.

➤ Changed low battery warning level from 2.8 Vdc to 2.3 Vdc.

➤ Changed low battery voltage condition to provide a HALARM warning pulse instead of clearing the ENABLE Meter Word bit.

➤ Eliminated power supply warnings from meter self-test.

➤ Corrected Ethernet session initialization conflict.

➤ Corrected DNP lock-up susceptibility on Port F and Port 2.

20070312



Date Code

A.7





➤ Improved crest factor metering issue.

➤ Added MAC address to VER command.

➤ Added settable Watt/VAR cutoff point.

➤ Added per-point scaling on DNP counters.

➤ Added frozen DNP counters—optional: object 21, 23.

➤ Added MV-90-specific protocol port settings.

➤ Added harmonic magnitude report and SELOGIC® values.

➤ Corrected Telnet timeout issue (returns to ACC level 0).

➤ Added fractional XFTR setting for Transformer Line Loss Compen-sation.

➤ Improved flagging of time/date changes in load profile report.

➤ Added Fast Messages:

20ENERGY

20DEM4Q

20PEAK4Q

20MET4Q

20060919



➤ Added support for Time-of-Use metering.

➤ Added Programmable Demand Reset.

➤ Enhanced response to large front-panel settings files.

➤ Enabled CTR/PTR settings changes with KYZ enabled.

➤ Added real and imaginary components to SELOGIC.

➤ Enhanced settings reads over long-distance Ethernet connection.

➤ Corrected TEST mode time-out.

➤ Corrected Volt-hour scaling.

➤ Enhanced TLL settings.

➤ Added MATH command.

20060519




20060420



➤ Corrected modem disconnect/VSSI conflict. 20060131



➤ Correct synchrophasor dropped packets.

➤ Saving Port 1 settings always restarts meter.

20051118



➤ Prevented possibility of meter disabling after a settings change.

➤ Ensured synchrophasor feature always responds to enable messages.

20051027



➤ Corrected contact input response to ac voltage. 20051003



Date Code

A.8





➤ Added Meter Gain Adjustment settings.

➤ Increased the range of the SET E command.

➤ Corrected Compressed Event Report header format error.

➤ Enhanced Configurable Display Points.

➤ Added signed VAR through Modbus.

➤ Enhanced SEL-5601 support of Raw Event Report.

➤ Allow field change of Meter form.

➤ Added multiple, simultaneous Modbus TCP/Telnet sessions.

➤ Added additional energy registers to Modbus map.

➤ Added Quadrant Bits to Meter Word bits.

➤ Corrected VAR quadrant accumulation error when at zero Power Factor.

➤ Added support for COMTRADE-formatted Event Reports.

20050817



➤ Corrected possible error condition when reading event reports. 20050617



➤ Fixed rollover in Modbus® energy registers.

➤ Improved Ethernet communication over large networks.

➤ Improved calculations for THD reporting.

➤ Corrected RAM Failure when using Ethernet on high-traffic net-work.

➤ Corrected TLL selection when in TEST mode.

➤ Corrected the need for power reset when changing from 232 to modem on Port 4.

➤ Added part number support for future power supply option.

➤ Improved handling of DNP map during firmware upgrade.

➤ Added AT string for setting of internal modem.

➤ Corrected VSSI/Event report conflict.

➤ Fixed SELOGIC® counters handling of default NA values.

➤ Added Energy cut-off point.

➤ Added fractional CTR/PTR settings.

➤ Extended maximum front panel time-out setting (FP_TO) to 120 minutes.

➤ Changed VBASE default setting to 120 V.

➤ Added additional KYZ/Test Mode settings (KEn_UNITS, KEn_SCALE, and KET).

➤ Added RESET button local bit.

➤ Added Date and Time of peak demand (MET D T).

➤ Provided field upgrade path from R108 to R110.

20050427



➤ Manufacturing process improvements.Note: Rewrites calibration constants and must be installed at SEL.

20041111



Date Code

A.9





➤ Add energy registers to DNP counter objects.

➤ Fix software flow control with SEL-2032/2030/2020 Communications Processors.

➤ VSSI reporting improvements.

➤ Correct error in Math Variable processing.

➤ Improve operation of modem at speeds below 9600 bps.

➤ Correct harmonic trigger oscillation.

➤ Correct MV-90 LDP multiple request issue introduced in R107/R507.

20040915



➤ Change TLL Inputs.

➤ Add Precision to Ke Setting.

➤ Correct RESET pushbutton functionality in TEST Mode.

20040511



➤ Manual update only. See Table A.3 for a summary of manual updates.

20040224



➤ Resolve Ethernet and Test Mode Conflict. 20040213



➤ Enable VB_RMS, VC_RMS on display points.

➤ Enable Date, Time, and Date/Time on display points.

➤ Enable DST support for Southern Hemisphere.

➤ Improved metering accuracy in reverse power flow conditions.

➤ Enable single-phase calibration testing of Form 5 meters.

20040130



➤ Resolve DNP and Test Mode conflict.

➤ Release SELBOOT R101, which allows firmware uploads on Port 3.

➤ Set PMDOK bit when phasor data is valid.

20031103



➤ Limits password string length to eight characters. 20030825



➤ Initial version. 20030730



Date Code

A.10


Firmware and Manual VersionsInstruction Manual

Instruction ManualThe date code at the bottom of each page of this manual reflects the creation or revision date.

Table A.3 lists the instruction manual release dates and a description of modifications. The most recent instruction manual revisions are listed at the top.

Table A.3 Instruction Manual Revision History (Sheet 1 of 2)

Revision Date Summary of Revisions

20130118 Section 4

➤ Added IB calculation method to Form 5 metering section under Metering Calculations.

Section 8

➤ Added Analog Control Values section.

Appendix A

➤ Updated for firmware version R212.

Appendix E

➤ Added DNP point explanations for power factor binary inputs.

20121114 Appendix A

➤ Updated for firmware version R137/R537 (see Table A.2).

20120823 Appendix A


20120521 Section 1

➤ Updated Low Energy Analog Voltage Inputs in Specifications.

Section 2

➤ Added torque mounting.

➤ Added Figure 2.10: Side- and Rear-Panel Drawings for Meters With LEA Inputs.

Section 3

➤ Added ACSELERATOR QuickSet Design section.

Section 4

➤ Added Table 4.12: FAULT Thresholds.

Section 9, Settings Sheets

➤ Added INOM Setting.

➤ Added VBASE Setting.

➤ Added UTC Offset Setting.

➤ Added UTC_OFF Setting.

➤ Added DNPSRC Setting.

Section 10

➤ Added Ethernet Port Address Resolution Protocol discussion

Appendix A


20120306 Appendix A


20120215 Section 1

➤ Clarified that Synchrophasors uses the Fast Message protocol in Specifications.

Appendix A


A.11


Firmware and Manual VersionsInstruction Manual

20120119 Section 1

➤ Added Fiber-Optic Ethernet specifications.

Section 4

➤ Added VSSI retrieval methods.

➤ Added Instrument Transformer Compensation.

Settings Sheets

➤ Changed CTR setting range.

Appendix A

➤ Updated for firmware versions R207 and R536/R136.

20111216 Appendix A


20110719 Section

➤ Updated Specifications for UL certification.

Appendix A

➤ Updated for manual edits only.

20110426 Appendix A


➤ Updated for firmware versions R135 and R535.

Table A.3 Instruction Manual Revision History (Sheet 2 of 2)

Revision Date Summary of Revisions



Appendix BSEL Distributed Port

Switch Protocol (LMD)

OverviewSEL Distributed Port Switch Protocol (LMD) permits multiple SEL meters to share a common communications channel. It is appropriate for low-cost, low-speed port switching applications where updating a real-time database is not a requirement.

SettingsUse the front-panel pushbuttons or the serial port SET P command to activate the LMD protocol. Change the port PROTO setting from the default SEL to LMD to reveal the following settings:

➤ PREFIX: One character to precede the address. This should be a character that does not occur in the course of other communications with the meter. Valid choices are one of the following: @, #, $, %, &. The default is @.

➤ ADDR: Two-character ASCII address. The range is 01 to 99. The default is 01.

➤ SETTLE: Time in seconds that transmission is delayed after the request to send (RTS line) asserts. This delay accommodates transmitters with a slow rise time.

Operation1. The meter ignores all input from this port until it detects the

prefix character and the two-byte address.

2. Upon receipt of the prefix and address, the meter enables echo and message transmission.

3. Wait until you receive a prompt before entering commands, to avoid losing echoed characters while the external transmitter is warming up.

4. Until the meter connection terminates, you can use the standard commands that are available when PROTO is set to SEL.

NOTE: You can use the front-panel pushbuttons to change the port settings to return to SEL protocol.

B.2


SEL Distributed Port Switch Protocol (LMD)Operation

5. The QUIT command terminates the connection. If no data are sent to the meter before the port time-up period, it automatically terminates the connection.

6. Enter the sequence <Ctrl+X> QUIT <Enter> before entering the prefix character if all meters in the multidrop network do not have the same prefix setting.


Appendix CSEL Communications Processors

SEL Communications ProtocolsThe SEL-734 Meter supports the protocols and command sets shown in Table C.1.

SEL ASCII Commands We originally designed SEL ASCII commands for communication between the meter and a human operator via a keyboard and monitor or a printing terminal. A computer with a serial port can also use the SEL ASCII protocol to communicate with the meter, collect data, and issue commands.

SEL Compressed ASCII Commands

The meter supports a subset of SEL ASCII commands identified as Compressed ASCII commands. Each of these commands results in a comma-delimited message that includes a checksum field. Most spreadsheet and database programs can directly import comma-delimited files. Devices with embedded processors connected to the meter can execute software to parse and interpret comma-delimited messages without expending the customization and maintenance labor needed to interpret nondelimited messages. The meter calculates a checksum for each line by numerically summing all of the bytes that precede the checksum field in the message. The program that uses the data can detect transmission errors in the message by summing the characters of the received message and comparing this sum to the received checksum.

Most commands are available only in SEL ASCII or Compressed ASCII format. Selected commands have versions in both standard SEL ASCII and Compressed ASCII formats. Compressed ASCII reports generally have fewer characters than conventional SEL ASCII reports, because the compressed reports reduce blanks, tabs, and other “white space” between data fields to a single comma.

Table C.1 Supported Serial Command Sets

Command Set Description

SEL ASCII Use this protocol to send ASCII commands and receive ASCII responses that are human readable with an appropriate terminal emulation program.

SEL Compressed ASCII Use this protocol to send ASCII commands and receive Compressed ASCII responses that are comma delimited for use with spreadsheet and database programs or for use by intelligent electronic devices.

SEL Fast Meter Use this protocol to send binary commands and receive binary meter and target responses.

SEL Fast Operate Use this protocol to receive binary control commands.

SEL Fast SER Use this protocol to receive binary Sequence Events Recorder unsolicited responses.

C.2


SEL Communications ProcessorsSEL Communications Protocols

Table C.2 lists the Compressed ASCII commands and contents of the command responses.

Interleaved ASCII and Binary Messages

SEL meters have two separate data streams that share the same physical serial port. Human data communications with the meter consist of ASCII character commands and reports that you view by using a terminal or terminal emulation package. The binary data streams can interrupt the ASCII data stream to obtain information; the ASCII data stream continues after the interruption. This mechanism uses a single communications channel for ASCII communication (transmission of an event report, for example) interleaved with short bursts of binary data to support fast acquisition of metering data. The device connected to the other end of the link requires software that uses the separate data streams to exploit this feature. However, you do not need a device to interleave data streams to use the binary or ASCII commands. Note that XON, XOFF, and CAN operations operate on only the ASCII data stream.

An example of using these interleaved data streams is when the SEL-734 communicates with an SEL communications processor. These SEL communications processors perform auto-configuration by using a single data stream and SEL Compressed ASCII and binary messages. In subsequent operations, the SEL communications processor uses the binary data stream for Fast Meter, and Fast Operate messages to populate a local database and to perform SCADA operations. At the same time, you can use the binary data stream to connect transparently to the SEL-734 and use the ASCII data stream for commands and responses.

SEL Fast Meter, Fast Operate, and Fast SER Messages

SEL Fast Meter is a binary message that you solicit with binary commands. Fast Operate is a binary message for control. The meter can also send unsolicited Fast SER messages and unsolicited synchrophasor messages automatically. If the meter is connected to an SEL communications processor, these messages provide the mechanism that the communications processor uses for SCADA or DCS functions that occur simultaneously with ASCII interaction.

SEL Application Guide AG95-10, Configuration and Fast Meter Messages, is a comprehensive description of SEL binary messages.

Table C.2 Compressed ASCII Commands

Command Response Access Level

BNAME ASCII names of Fast Meter status bits 0

CASCII Configuration data of all Compressed ASCII commands available at access levels > 0

0

CEVENT Event report 1

CHISTORY List of events 1

DNAME ASCII names of digital I/O reported in Fast Meter 0

ID Meter identification 0

SNS ASCII names for SER data reported in Fast Meter 0

C.3


SEL Communications ProcessorsSEL Communications Processor

SEL Communications ProcessorSEL offers SEL communications processors, powerful tools for system integration and automation. The SEL-2020 and SEL-2030 series are similar, except that the SEL-2030 series has two slots for network protocol cards. These devices provide a single point of contact for integration networks with a star topology as shown in Figure C.1.

Figure C.1 SEL Communications Processor Star Integration Network

In the star topology network in Figure C.1 the SEL communications processor offers the following substation integration functions:

➤ Collection of real-time data from SEL and non-SEL IEDs

➤ Calculation, concentration, and aggregation of real-time IED data into databases for SCADA, HMI, and other data consumers

➤ Access to the IEDs for engineering functions including configuration, report data retrieval, and control through local serial, remote dial-in, and Ethernet network connections

➤ Simultaneous collection of SCADA data and engineering connection to SEL IEDs over a single cable

➤ Distribution of IRIG-B time synchronization signal to IEDs based on external IRIG-B input, internal clock, or protocol interface

➤ Automated dial-out on alarms

The SEL communications processors have 16 serial ports plus a front port. This port configuration does not limit the size of a substation integration project, because you can create a multitiered solution as shown in Figure C.2. In this multitiered system, the lower-tier SEL communications processors forward data to the upper-tier SEL communications processor that serves as the central point of access to substation data and station IEDs.

SEL CommunicationsProcessor

To Engineering

Modem

To SCADA

Local HMI

SEL IED SEL IED SEL IED Non-SEL IED

C.4


SEL Communications ProcessorsSEL Communications Processor

The SEL-734 supports the commands as listed in Table C.1 for the various communication processors.

Figure C.2 Multitiered SEL Communications Processor Architecture

You can add additional communications processors to provide redundancy and eliminate possible single points of failure. SEL communications processors provide an integration solution with a reliability comparable to that of SEL meters. In terms of MTBF (mean time between failures), SEL communications processors are 100 to 1000 times more reliable than computer-based and industrial technology-based solutions.

Configuration of an SEL communications processor is different from other general-purpose integration platforms. You can configure SEL communications processors with a system of communication-specific keywords and data movement commands rather than programming in C or another general-purpose computer language. SEL communications processors offer the protocol interfaces listed in Table C.3.

Table C.1 SEL-734 Fast Message Commands

Communications Processor

SEL-2020 SEL-2030 SEL-2032

Commands Supported

B20METER B20METER B20METER

B20DEMAND B20DEMAND B20DEMAND

B20TARGET B20TARGET B20TARGET

A20HISTORY A20HISTORY A20HISTORY

A20STATUS A20STATUS A20STATUS

A20EVENT A20EVENT A20EVENT

A20EVENT A20EVENT A20EVENT

B20ENERGY

B20DEM4Q

B20PEAK4Q

B20MET4Q


To Engineering

ModemTo SCADA

Local HMI

SEL IED

SEL IED

SEL IED

Non-SEL IED

SEL IED

SEL IED

SEL IED

Non-SEL IED



C.5


SEL Communications ProcessorsSEL Communications Processor and Meter Architecture

SEL Communications Processor and Meter Architecture

You can apply SEL communications processors and SEL meters in a limitless variety of applications that integrate, automate, and improve station operation. Most system integration architectures utilizing SEL communications processors involve either developing a star network or enhancing a multidrop network.

Developing Star Networks

The simplest architecture using both the SEL-734 and an SEL communications processors is shown in Figure C.1. In this architecture, the SEL communications processor collects data from the SEL-734 and other station IEDs. The SEL communications processor acts as a single point of access for local and remote data consumers (local HMI, SCADA, engineers). The communications processor also provides a single point of access for engineering operations including configuration and the collection of report-based information.

By configuring a data set optimized to each data consumer, you can significantly increase the utilization efficiency on each link. A system that uses an SEL communications processor to provide a protocol interface to an RTU will have a shorter lag time (data latency); communication overhead is much less for a single data exchange conversation to collect all substation data (from a communications processor) than for many conversations required to collect data directly from each individual IED. You can further reduce data latency by connecting an SEL communications processor directly to the SCADA master and eliminating redundant communication processing in the RTU.

The SEL communications processor is responsible for the protocol interface, so you can install, test, and even upgrade the system in the future without disturbing protective meters and other station IEDs. This insulation of the protective devices from the communications interface assists greatly in

Table C.3 SEL Communications Processors Protocol Interfaces

Protocol Connect to

DNP3 Level 2 Slave DNP3 masters

Modbus® RTU Modbus masters

Modbus® TCP Modbus masters with Ethernet

SEL ASCII/Fast Message Slave SEL protocol masters

SEL ASCII/Fast Message Master SEL protocol slaves including other communica-tions processors and SEL meters

ASCII and Binary auto messaging SEL and non-SEL IED master and slave devices

Modbus Plusa

a Requires SEL-2711 Modbus Plus protocol card.

Modbus Plus peers with global data and Modbus Plus masters

FTP (File Transfer Protocol)b

b Requires SEL-2701 Ethernet Processor.

FTP clients

Telnetb Telnet servers and clients

UCA2 GOMSFEb UCA2 protocol masters

UCA2 GOOSEb UCA2 protocol and peers

C.6


SEL Communications ProcessorsSEL Communications Processor and Meter Architecture

situations where different departments are responsible for SCADA operation, communication, and protection.

SEL communications processors equipped with an SEL-2701 can provide a UCA2 interface to SEL-734 meters and other serial IEDs. The SEL-734 data appear in models in a virtual device domain. The combination of the SEL-2701 with an SEL communications processor offers a significant cost savings because you can use existing IEDs or purchase less expensive IEDs. For full details on applying the SEL-2701 with an SEL communications processor, see the SEL-2701 Ethernet Processor Instruction Manual.

The engineering connection can use either an Ethernet network connection through the SEL-2701 or a serial port connection. This versatility will accommodate the channel that is available between the station and the engineering center. SEL software, including the ACSELERATOR QuickSet® SEL-5030 Software Program, can use either a serial port connection or an Ethernet network connection from an engineering workstation to the meters in the field.

Enhancing Multidrop Networks

You can also use an SEL communications processor to enhance a multidrop architecture similar to the one shown in Figure C.3. In this example, the SEL communications processor enhances a system that uses the SEL-2701 with an Ethernet HMI multidrop network. In the example, there are two Ethernet networks, the SCADA LAN and the Engineering LAN. The SCADA LAN provides real-time data directly to the SCADA Control Center via a protocol gateway and to the HMI (Human Machine Interface).

In this example, the SEL communications processor provides the following enhancements when compared to a system that employs only the multidrop network:

➤ Ethernet access for IEDs with serial ports

➤ Backup engineering access through the dial-in modem

➤ IRIG-B time signal distribution to all station IEDs

➤ Integration of IEDs without Ethernet

➤ Single point of access for real-time data for SCADA, HMI, and other uses

➤ Significant cost savings through use of existing IEDs with serial ports

C.7


SEL Communications ProcessorsSEL Communications Processor Example

Figure C.3 Enhancing Multidrop Networks With SEL Communications Processors

SEL Communications Processor ExampleThis example demonstrates the data and control points available in the SEL communications processor when you connect an SEL-734. Figure C.4 shows the physical configuration this example uses.

Figure C.4 Example SEL Meter and SEL Communications Processor Configuration


Modem

To SCADA Control Center,RTU, or Protocol Gateway To Engineering

HMI/Local Engineering

Access

SEL-734 Meter

Hub Hub

Ethernet IED

SCADA Ethernet LAN

EIA-232

EngineeringEthernet LAN

SEL-734 Meter SEL Relay Non-SEL IED


SEL-734 Meter

Personal Computer

Port F

Port 1

Cable C273A

Cable C234A

C.8



Table C.4 shows the Port 1 settings for the SEL communications processor.

Data Collection The SEL communications processor is configured to collect data from the SEL-734 through use of the auto-messages listed in Table C.5. Disable auto-messages with the FMR1–FMR4 settings if eight or more SEL-734 meters are connected to an SEL communications processor, and the communications processor issues the following report:Attempting auto-configuration... FAILED, auto-configuration error This error indicates that the amount of data that the SEL-734 meters are sending during an auto configuration attempt exceeds the capability of the communications processor. See Fast Message Settings on page SET.8 for additional details about the FMR1–FMR4 settings.

Table C.6 shows the automessage (Set A) settings for the SEL communications processor.

Table C.4 SEL Communications Processor Port 1 Settings

Setting Name Setting Description

DEVICE S Connected device is an SEL device

CONFIG Y Allow auto-configuration for this device

PORTID “Meter 1” Name of connected metera

a Automatically collected by the SEL communications processor during auto-configuration.

BAUD 19200 Channel speed of 19200 bits per seconda

DATABIT 8 Eight data bitsa

STOPBIT 1 One stop bit

PARITY N No parity

RTS_CTS Y Hardware flow control enabled

TIMEOUT 5 Idle time-out that terminates transparent connections of 5 minutes

Table C.5 SEL Communications Processor Data Collection Auto-messages

Message Data Collected

20METER Power system metering data

20ENERGY Energy metering data (enable and disable with FMR1)

20DEM4Q Four-quadrant demand metering data (enable and disable with FMR2)

20PEAK4Q Four-quadrant peak demand metering data (enable and disable with FMR3)

20MET4Q Four-quadrant power system metering data (enable and disable with FMR4)

Table C.6 SEL Communications Processor Port 1 Automatic Messaging Settings (Sheet 1 of 2)


AUTOBUF Y Save unsolicited messages

STARTUP “ACC\nOTTER\n” Automatically log in at Access Level 1

SEND_OPER Y Send Fast Operate messages for remote bit and breaker bit control

REC_SER N Automatic sequential events recorder data collection disabled

C.9



Table C.7 shows the map of regions in the SEL communications processor for data collected from the SEL-734.

Metering Data Table C.8 shows the list of meter data available in the SEL communications processor and the location and data type for the memory areas within D1 (Data Region 1). The type field indicates the data type and size. The type “int” is a 16-bit integer. The type “float” is a 32-bit IEEE floating point number.

NOCONN NA No SELOGIC control equation entered to selectively block connections to this port

MSG_CNT 3 Three automessages

ISSUE1 P00:00:01.0 Issue Message 1 every second

MESG1 20METER Collect metering data

ISSUE2 P00:00:01.0 Issue Message 2 every second

MESG2 20TARGET Collect Meter Word bit data

ISSUE3 P00:01:00.0 Issue Message 3 every minute

MESG3 20DEMAND Collect demand metering data

ARCH_EN N Archive memory disabled

USER 0 No USER region registers reserved

Table C.7 SEL Communications Processor Port 1 Region Map

RegionData CollectionMessage Type

Region Name Description

D1 Binary METER Meter metering data

D2 Binary TARGET Meter Word bit data

D3 Binary DEMAND Demand metering data

D4–D8 n/a n/a Unused

A1–A3 n/a n/a Unused

USER n/a n/a Unused

Table C.6 SEL Communications Processor Port 1 Automatic Messaging Settings (Sheet 2 of 2)


Table C.8 Communications Processor METER Region Map (Sheet 1 of 2)

Item Starting Address Type

_YEAR 2000h int

DAY_OF_YEAR 2001h int

TIME (ms) 2002h int[2]

MONTH 2004h char

DATE 2005h char

YEAR 2006h char

HOUR 2007h char

MIN 2008h char

SECONDS 2009h char

MSEC 200Ah int

IA (A) 200Bh float[2]

C.10



Control Points The SEL communications processor can automatically pass control messages, called Fast Operate messages, to the SEL-734. You must enable Fast Operate messages through use of the FASTOP setting in the SEL-734 port settings for the port connected to the SEL communications processor. You must also enable Fast Operate messages in the SEL communications processor by setting the automessage setting SEND_OPER equal to Y.

When you enable Fast Operate functions, the SEL communications processor automatically sends messages to the meter for changes in remote bits RB01–RB16 on the corresponding SEL communications processor port. In this example, if you set RB01 on Port 1 in the SEL communications processor, it automatically sets RB01 in the SEL-734.

IB (A) 200Fh float[2]

IC (A) 2013h float[2]

IN (A) 2017h float[2]

VA (V) 201Bh float[2]

VB (V) 201Fh float[2]

VC (V) 2023h float[2]

FREQ (Hz) 2027h float[2]

EA (MWhA Net) 202Bh float[2]

EB (MWhB Net) 202Fh float[2]

EC (MWhC Net) 2033h float[2]

E3 (MWh3P Net) 2037h float[2]

IAB (A) 203Bh float[2]

IBC (A) 203Fh float[2]

ICA (A) 2043h float[2]

VAB (V) 2047h float[2]

VBC (V) 204Bh float[2]

VCA (V) 204Fh float[2]

PA (MW) 2053h float

QA (MVAR) 2055h float

PB (MW) 2057h float

QB (MVAR) 2059h float

PC (MW) 205Bh float

QC (MVAR) 205Dh float

P (MW) 205Fh float

Q (MVAR) 2061h float

I0 (A) 2063h float[2]

I1 (A) 2067h float[2]

I2 (A) 206Bh float[2]

V0 (V) 206Fh float[2]

V1 (V) 2073h float[2]

V2 (V) 2077h float[2]

Table C.8 Communications Processor METER Region Map (Sheet 2 of 2)

Item Starting Address Type


Appendix DSetting SELOGIC Control Equations

OverviewSELOGIC® control equations combine meter control elements with logic operators to create custom control schemes. This appendix shows how to set the control elements (Meter Word bits) in the SELOGIC control equations.

Additional SELOGIC control equation setting details are available in Section 9: Settings (see also SEL-734 Settings Sheets). See the SHO Command (Show/View Settings) on page 10.24 for a list of the factory settings shipped with the standard SEL-734.

Meter Word BitsMost of the control element logic outputs shown in the various figures in Section 4: Metering through Section 9: Settings are Meter Word bits (labeled as such in the figures). Each Meter Word bit has a label name and can be in either of the following states:

1 (logical 1) or 0 (logical 0)

Logical 1 represents an element being picked up, timed out, or otherwise asserted.

Logical 0 represents an element being dropped out or otherwise deasserted.

A complete listing of Meter Word bits and their descriptions are referenced in Table 9.4.

Meter Word bits are used in SELOGIC control equations, which are explained in SELogic Control Equations on page D.1.

SELOGIC Control EquationsMany of the control element logic inputs shown in the various figures in Section 4: Metering through Section 9: Settings are SELOGIC control equations (labeled SELOGIC Settings in most of the figures).

SELOGIC control equations are set with combinations of Meter Word bits to accomplish such functions as the following:

➤ Use of optoisolated inputs to assign functions

➤ Operation of output contacts

Traditional or advanced custom schemes can be created with SELOGIC control equations.

D.2


Setting SELOGIC Control EquationsSELOGIC Control Equations

SELOGIC Control Equation Operators

SELOGIC control equation settings use logic similar to Boolean algebra logic, combining Meter Word bits together through use of one or more of the six SELOGIC control equation operators listed in Table D.1.

Operators in a SELOGIC control equation setting are processed in the order shown in Table D.1.

SELOGIC Control Equation Parentheses Operator ( )More than one set of parentheses ( ) can be used in a SELOGIC control equation setting. For example, the following SELOGIC control equation setting has two sets of parentheses:

SV7 = (SV07 OR IN101) AND (MV01 OR OUT103)

In the above example, the logic within the parentheses is processed first and then the two resultants are ANDed together. Parentheses cannot be nested (parentheses within parentheses) in a SELOGIC control equation setting.

SELOGIC Control Equation NOT OperatorThe NOT operator is applied to a single Meter Word bit and to multiple elements (within parentheses). Following are examples of both.

EXAMPLE D.1 Default LED Logic

T01_LED := NOT 27A

LED1 is lit when 27A is not asserted (logic 0). When 27A asserts (logic 1), LED1 turns off.

EXAMPLE D.2 Alarm Output Using the NOT Operator

OUT401 := NOT (HALARM OR SALARM)

OUT401 is asserted (logic 1) when HALARM and SALARM Meter Word bits are deasserted. This setup can be used to make an alarm contact.

SELOGIC Control Equation Rising Edge Operator R_TRIGThe rising edge operator R_TRIG is applied to individual Meter Word bits only, not to groups of elements within parentheses. For example, the SELOGIC control equation event report generation setting uses rising edge operators:

ER := R_TRIG OUT103

The Meter Word bit in this setting example is: OUT103 (Output contact OUT103).

When setting ER sees a logical 0 to logical 1 transition, it generates an event report (if the meter is not already generating a report that encompasses the new transition). The rising edge operator in the above setting example allows setting ER to see each transition individually.

Table D.1 SELOGIC Control Equation Operators (Listed in Processing Order)

Operator Logic Function

R_TRIG rising edge detect

F_TRIG falling edge detect

( ) parentheses

NOT NOT

AND AND

OR OR

D.3


Setting SELOGIC Control EquationsSELOGIC Control Equations

SELOGIC Control Equation Falling Edge Operator F_TRIGThe falling edge operator F_TRIG is applied to individual Meter Word bits only, not to groups of elements within parentheses. The falling edge operator F_TRIG operates similarly to the rising edge operator, but looks for Meter Word bit deassertion (element going from logical 1 to logical 0). The falling edge operator in front of a Meter Word bit sees this logical 1 to logical 0 transition as a falling edge and asserts to logical 1 for one processing interval.

Set All SELOGIC Control Equations

All SELOGIC control equations must be set one of the following ways (they cannot be blank):

➤ Single Meter Word bit (e.g., FLTBK := IN101)

➤ Combination of Meter Word bits (e.g., OUT102 := RB01 AND RB03 OR NOT RB02)

➤ Directly to logical 1 (e.g., T01_LED := 1)

➤ Directly to logical 0 (e.g., SV01 := 0)

Set SELOGIC Control Equations Directly to 1 or 0SELOGIC control equations can be set directly to the following:

1 (logical 1) or 0 (logical 0)

instead of with Meter Word bits. If a SELOGIC control equation setting is set directly to 1, it is always asserted/on/enabled. If a SELOGIC control equation setting is set equal to 0, it is always deasserted/off/disabled.

Under the SHO Command (Show/View Settings) on page 10.24, note that a number of the factory SELOGIC control equation settings are set directly to 1 or 0.

SELOGIC Control Equation Limitations

Any single SELOGIC control equation setting is limited to 15 Meter Word bits that can be combined together with the SELOGIC control equation operators listed in Table D.1. If this limit must be exceeded, use a SELOGIC control equation variable (SELOGIC control equation settings SV01 through SV32) as an intermediate setting step.

For example, assume that the fault equation (SELOGIC control equation fault setting FAULT) needs more than 15 Meter Word bits in its equation setting. Instead of placing all Meter Word bits into FAULT, program some of them into the SELOGIC control equation setting SV01. Next, use the resultant SELOGIC control equation variable output (Meter Word bit SV01) in the SELOGIC control equation trip setting FAULT.

SELOGIC control equation settings that are set directly to 1 (logical 1) or 0 (logical 0) also have to be included in these limitations with each such setting counted as one Meter Word bit.

Table D.2 SELOGIC Control Equation Settings Limitations for the SEL-734 Meter Model

Model Number

SELOGIC Control Equation Settings Limitations per Setting Group

0734 Total number of elements ≤ 486Total number of rising edge or falling edge operators ≤ 54

D.4


Setting SELOGIC Control EquationsProcessing Order and Processing Interval

Processing Order and Processing Interval

The meter elements and logic (and corresponding SELOGIC control equation settings and resultant Meter Word bits) are processed in the order shown in Table D.3 (top to bottom). They are processed every processing interval (25 ms), and the Meter Word bit states (logical 1 or logical 0) are updated with each interval. Once a Meter Word bit is asserted, it retains the state (logical 1 or logical 0) until it is updated again in the next processing interval.

Table D.3 Processing Order of Meter Elements and Logic (Top to Bottom)

Meter Elements and Logic

Processing Orderfor SELOGIC Control

Equations andMeter Word Bits

Instruction Manual Reference

Analog and digital data acquisition Expansion Slot #2, I/O Board

IN101–IN102IN401–IN404

Section 8, Section 9, and Section 10

Remote Control Switches RB01–RB16 Section 8

Voltage Sag/Swell/Interruption Elements

SAGxx, SWxx,INTxx, where xx = A,B, C, AB, BC, CA, or 3P

Section 6

SELOGIC Control Equation Variables/Timers

SV01–SV32,SV01T–SV32T

Section 8

Math SELOGIC Variables MV01–MV32 Section 8

Fault detector for Target Logic and Metering

FAULT Section 4 and Section 9

Output Contact Equations Expansion Slot #2, I/O Board

OUT101–OUT103OUT401–OUT404

Section 8

Latch Bits Set/Reset Equations SET01–SET32,RST01–RST32

Section 8

MIRRORED BITS® Transmit Equations

TMB1A–TMB8A,TMB1B–TMB8B

Appendix G

Event Report Trigger ER1–ER3 Section 6

Display Points DP01–DP32 Section 8

SELOGIC Counter Equations SC01–SC32 Section 8

Software Alarm SALARM Section 8


Appendix EDistributed Network Protocol

OverviewThe SEL-734 Meter supports Distributed Network Protocol (DNP3) Level 2 Slave protocol. This includes access to metering data, contact I/O, targets, sequential events recorder, meter summary event reports. The SEL-734 also supports DNP point remapping.

Binary Inputs The SEL-734 can write Meter Word Bits to the DNP master using Binary Inputs. The SEL-734 updates binary inputs 0–799 and 1600–1643 approximately once per second. The time stamps for binary input events may be up to two seconds behind the time of actual occurrence. The meter only has one row of LEDs (fault targets) and the upper byte represents targets. This means that 0000001 will read 256.

The SEL-734 derives binary inputs 800–1599 from the Sequential Events Recorder (SER), that are updated once per second with a time stamp of actual occurrence. Only points recorded in the SER1, SER2, or SER3 lists (SET R) generate events.

Power Factor The SEL-734 reports both displacement power factor and true power factor. Each quantity has a DNP analog input register and an associated DNP binary input.

The SEL-734 asserts the associated binary input when the power factor is leading. Table E.1 lists the DNP registers of the analog inputs and the associated binary input.

For example, assume that the A-phase displacement and true power factor is 0.85 leading. For this case, the Binary Input points 1632 and 1636 assert to indicate that the power factor is leading.

Binary Outputs The DNP master can assert and deassert SEL-734 remote bits, reset energy, and reset demand by writing binary outputs to the SEL-734.

Binary outputs allow external control of:

➤ Remote bits

➤ Remote bit pairs

➤ Contact outputs

Table E.1 Power Factor Analog and Binary Points

QuantityDNP Index of Analog Input

DNP Index of Binary Input

Displacement Power Factor 96–99 1632–1635

True Power Factor 100–103 1636–1639

E.2


Distributed Network ProtocolOverview

➤ Next event bit

➤ Reset energy or demand through a remote bit

Binary/Frozen Counters

The SEL-734 updates binary counters once per second and reports a time-stamped event when a counter value changes beyond its deadband setting. The time stamps for binary counter events may be up to two seconds behind the time of actual occurrence.

Three types of data are available as binary counters:

➤ SELOGIC Counters

➤ Energy

➤ Load Profile Records

SELOGIC CountersThe binary counter indices 07–22 report SELOGIC counter values SC01–SC32.

EnergyUse binary counters for reporting energy values because they automatically roll over at their full-scale values: 216 or 232 depending on variation. The SEL-734 reports DNP energy counters in primary units affected by the DECPLE setting and per-point scaling.

Load ProfileThe SEL-734 reports load profile as the most recent record, or in fifty-record groups when a DNP master writes the time and date of the earliest record using analog outputs 40–45. After the DNP master writes to the date and time analog output, the SEL-734 will update the DNP LDP points with the load profile data. This update will take 5–30 seconds. Use one of the following three methods to ensure that the SEL-734 has successfully updated the DNP LDP points before the master reads the load profile data.

➤ Wait 30 seconds after writing the time and date

➤ Monitor the LDP Data Ready Binary Input flag and read after the bit is set

➤ Monitor the LDP Data Ready Counter Input flag and read after the bit is set

The SEL-734 reports DNP Load Profile counters (Object 20, Index 40–1008) in secondary units scaled by 100. Load Profile counter information rolls over at 9,999,999.99. SEL recommends using 32-bit counter information because the 16-bit load profile counter information does not rollover in a predictable manor.

The SEL-734P supports 12 independent load profile recorders: LDP1, LDP2, LDP3, ... LDP12. Upon power-up, the SEL-734P defaults to and reports LDP1 recorder data. To retrieve LDP2 data, select and write a value of 1 to Analog Output (Object 40, 41) point 39 before retrieving LDP data. Continue this process for recorders 3–12 by writing a value of 2 for LDP3, 3 for LDP4, and so forth. The SEL-734 returns a format error if the master writes a value outside of the range 0–11. If the SEL-734 does not support the recorders LDP2–LDP12, it will always report LDP1 regardless if the master writes a 0–11 to Analog Output (Object 40, 41) point 39.

E.3


Distributed Network ProtocolOverview

VSSIThe SEL-734 reports VSSI as the most recent record or in 50-record groups when a DNP master writes the time and date of the earliest record using analog outputs 46–51. After the DNP master writes to the date and time analog output, the SEL-734 will update the DNP VSSI points with the VSSI data. This update will take 5–30 seconds. Use one of the following three methods to ensure that the SEL-734 has successfully updated the DNP VSSI points before the master reads the VSSI data.

➤ Wait 30 seconds after writing the time and date.

➤ Monitor the VSSI Data Ready Binary Input flag and read after the bit is set.

➤ Monitor the VSSI Data Ready Counter Input flag and read after the bit is set.

The status of a VSSI record is reported as defined as follows (see Table 6.6):

The Phase VSSI columns are defined as follows (see Table 6.5):

Analog Inputs The SEL-734 reports analog input quantities to the master optimized for all quantities except for energy values. Analog inputs peak at their binary full-scale values, 216 or 232 depending on variation, and do not roll over. Analog inputs represent angles in degrees, scaled by 100.

Analog Outputs The SEL-734 accepts analog output values from the master for use in SELOGIC control equations and the 4AO/4DO output card. Analog outputs can also write the time and date of load profile records available through binary counters.

Table E.2 VSSI Record Status Report Definitions

DNP Value VSSI Definition

0 Not Ready

1 R (Ready)

2 P (Predisturbance)

3 F (Fast recording mode)

4 E (End)

5 M (Medium recording mode)

6 S (Slow recording mode)

7 D (Daily recording mode)

8 X (Data overflow)

9 Checksum Error (all other values will be 0)

10 Data Overwrite (all other values will be 0)

Table E.3 Phase VSSI Column Definitions

DNP Value VSSI Definition

0 . (No bits asserted phase)

1 O (Overvoltage)

2 U (Undervoltage)

3 I (Interruption)

E.4


Distributed Network ProtocolConfiguration

Miscellaneous ➤ Object 50 (Time and Date): Object 50 function code 1 polls return SEL-734 internal time and date. To set SEL-734 time, use function code 2 to write the time and date to Object 50. Adjust the TIMERQ setting to determine the frequency with which the meter requests DNP time synchronization. Set the TIMERQ setting to M to disable time synchronization requests but cause the meter to still accept and apply time synchronizations from the master; set the TIMERQ setting to I to cause the meter to ignore time synchronizations from the master when another time source, such as IRIG-B, takes precedence.

When the DNPSRC settings is set to UTC, the SEL-734 interprets the time from the master as a UTC time. If a UTC offset is configured, the meter applies this offset to the time read from the DNP master. When the DNPSRC setting is set to LOCAL, the SEL-734 interprets the time from the master as a local time. In this case, the SEL-734 does not apply any offset to the time read from the master.

The SEL-734 always reports local time.

➤ Object 60 (Class Data): Object 60 polls return Class 0, 1, 2, and 3 data assigned to the ECLASSB, ECLASSC, and ECLASSA settings.

➤ Object 80, (Internal Indications): Object 80 polls return the internal indicator (IIN) bits specified by the DNP protocol. The SEL-734 sets the “Device Trouble” bit if the meter is disabled. Write “0” to bit 7 to clear the “Restart” bit.

ConfigurationDNP Operation To configure a port for DNP, set the port PROTO setting to DNP. Refer to

SEL-734 Settings Sheets for a list of all DNP settings.

Default Data Map Table E.4 shows the SEL-734 default DNP data map. Use the remapping feature to customize the data map for your application, see Configurable Data Mapping on page E.5.

Default Variations Table E.5 shows the default response for each object when a DNP master requests variation 0.

Table E.4 SEL-734 DNP3 Default Data Map

DNP Object Type

Description Default Map

01, 02 Binary Inputs 81–87, 90–95, 1600–1608, 1616–1619, 1632–1635

10, 12 Binary Outputs 16–22

20, 22 Counter Inputs 0

30, 32 Analog Inputs 0–7, 36–41, 84–95, 104, 112, 113, 120, 121, 303–309

40, 41 Analog Outputs 0

E.5



Configurable Data Mapping

One of the most powerful features of the SEL-734 implementation is the ability to remap DNP data with per point scaling and deadbands. Remapping is the process of selecting data from the reference map and organizing it into a smaller data set optimized for your application. Use the SEL-734 Settings Driver in ACSELERATOR QuickSet to remap and apply per-point scaling and deadbands to DNP maps. The map consists of five indices as described under Overview on page E.1. The order of points in the DNP map determines the order that the meter reports to the DNP master. If a value is not in the map, it is unavailable to the DNP master.

Per Point Scaling and DeadbandsScaling factors allow you to overcome the limitations imposed by the integer nature of Objects 30 and 32. For example, the meter rounds a value of 11.4 Amps to 11 Amps. Use the scaling to include decimal point values by multiplying by a number larger than one. If you use 10 as a scaling factor, 11.4 Amps will be transmitted as 114. You must divide the value by 10 in the master device to see the original value including one decimal place.

You can also use scaling to avoid overflowing the 16-bit maximum integer value of 32767. If you have a value that can reach 157834, you cannot send it by using DNP 16-bit analog object variations. Use a scaling factor of 0.1 so that the maximum value reported is 15783. You must multiply the value by 10 in the master to see a value of 157830. You will lose some precision as the last digit is rounded in the scaling process, but you can transmit the scaled value by using standard DNP Objects 30 and 32.

Change the DNP analog input map with per point scaling and deadband by entering DNP AI <Enter>. The “;” character is used as a scaling prefix, and the “:” character is used as a deadband prefix. DNP counters are scaled similarly. Per point scaling and deadband entries are not required.

=>>DNP AI <Enter>

Enter the new DNP Analog Input map0 2 4 6 112;5 28;0.2 17:10 1;1:15 <Enter>

=>>

Class Scaling and DeadbandsClass scaling (DECPLA, DECPLV, and DECPLM) and deadband (ANADBA, ANADBV, and ANADBM) settings are applied to all indices that do not have per point entries. For the class scaling settings, select 0 to multiply by 1, 1 for 10, 2 for 100, or 3 for a 1000.

Table E.5 SEL-734 DNP3 Default Variations

DNP Object Type Description Default Variation

01,02 Binary Inputs 2

10,12 Binary Outputs 2

20,22 Counter Inputs 5

21,23 Frozen Counters 1

30 Analog Inputs 4

32 Analog Inputs 2

40,41 Analog Outputs 2

E.6



Use the DNP BO command to change the binary output map. DNP AO, and DNP BI operate in a similar manner.

=>>DNP BO <Enter>

Enter the new DNP Binary Output map0 1 2 3 4 5 6 7

Save Changes(Y/N)? Y <Enter>

=>>

Change the DNP counter map with per point deadbands by entering DNP C <Enter>. These settings are entered in a manner similar to entering analog input settings.

Table E.6 includes the default object map supported by the SEL-734. Note that single phase elements are only available with a Form 9 meter.

Table E.6 DNP3 Device Profile (Sheet 1 of 12)

DNP Object Type

Index Description Scaling and Deadband

Binary Inputs

01,02 000–799 Meter Word—refer to Table 9.3 for indices. Unused indices will return a zero.

01,02 800–1599 Consecutively numbered SER indices.

01,02 1600–1606 Meter front panel targets

01,02 1607–1615 Reserved

01,02 1616 Meter disabled

01,02 1617 Meter diagnostic failure

01,02 1618 Meter diagnostic warning

01,02 1619 An unread event is available.

01,02 1620 Settings change or meter restart

01,02 1621 LDP Data Ready

01,02 1622 VSSI Data Ready

01,02 1623 Reserved for future status point

01,02 1624–1631 Reserved

01,02 1632–1635 Displacement power factor leading for A, B, C and 3-phase

01,02 1636–1639 True power factor leading for A, B, C and 3-phase

01,02 1640–1647 Reserved

Binary Outputs

10,12 00–15 Remote bits RB01–RB16

10,12 16–18 OUT101–OUT103

10,12 19– 22 OUT401–OUT404

10,12 23 Reserved

10,12 24–31 Remote bit pairs RB01–RB16

10,12 32–40 Reserved

10,12 41 Read next event


10,12 50 Include Interharmonics in Harmonic Values

E.7



NOTE: Index 50 default is 0. A value of zero does not include interharmonics in harmonic magnitudes and percentages. Write 1 to index 50 to include interharmonics in harmonic magnitudes and percentages.

Counter Inputs


20,22 07–22 SELOGIC Counters 1–16

20,22 23–24 Energy—A-phase Wh IN and OUT DECPLE

20,22 25–26 Energy—B-phase Wh IN and OUT DECPLE

20,22 27–28 Energy—C-phase Wh IN and OUT DECPLE

20,22 29–30 Energy—3-phase Wh IN and OUT DECPLE

20,22 31–32 Energy—A-phase VARh IN and OUT DECPLE

20,22 33–34 Energy—B-phase VARh IN and OUT DECPLE

20,22 35–36 Energy—C-phase VARh IN and OUT DECPLE

20,22 37–38 Energy—3-phase VARh IN and OUT DECPLE

20,22 2153–2159 Reserved

20,22 2380 Energy—MVRHAI_LD DECPLE

20,22 2381 Energy—MVRHAI_LG DECPLE

20,22 2382 Energy—MVRHAO_LD DECPLE

20,22 2383 Energy—MVRHAO_LG DECPLE

20,22 2384 Energy—MVRHBI_LD DECPLE

20,22 2385 Energy—MVRHBI_LG DECPLE

20,22 2386 Energy—MVRHBO_LD DECPLE

20,22 2387 Energy—MVRHBO_LG DECPLE

20,22 2388 Energy—MVRHCI_LD DECPLE

20,22 2389 Energy—MVRHCI_LG DECPLE

20,22 2390 Energy—MVRHCO_LD DECPLE

20,22 2391 Energy—MVRHCO_LG DECPLE

20,22 2392 Energy—MVRH3I_LD DECPLE

20,22 2393 Energy—MVRH3I_LG DECPLE

20,22 2394 Energy—MVRH3O_LD DECPLE

20,22 2395 Energy—MVRH3O_LG DECPLE

20,22 2396–2399 Energy—Volt Hours—VHA, VHB, VHC (VHAB, VHBC, VHCA if Delta), VH3

DECPLE

20,22 2400–2404 Energy—Amp Hours—IHA, IHB, IHC, IHN, IH3 DECPLE

20,22 2405 Sign of Energy Value MWH3_NET (0 for positive, 1 for nega-tive)

20,22 2406 Sign of Energy Value MVRH3_NET (0 for positive, 1 for nega-tive)

20,22 2407 Energy—MWH3_NET DECPLE

20,22 2408 Energy—MVRH3_NET DECPLE

20,22 2409 Power—MVR3I_LD DECPLM

20,22 2410 Power—MVR3I_LG DECPLM

20,22 2411 Power—MVR3O_LD DECPLM


DNP Object Type


E.8



20,22 2412 Power—MVR3O_LG DECPLM

20,22 2413–2449 Reserved

Status of Monthly Energy Values0 Power fail within interval

1 Clock reset forward during interval

2 Clock reset backward during interval

3 TEST mode data (meter in test mode during interval)

4 Invalid Frozen Data (invalid frozen quantities, invalid checksum, energy registers reset or changed, or first time meter powers up

5 Invalid Consumed Data (invalid consumed quantities, invalid checksum, energy registers reset or changed, or first time meter powers up

20,22 2900 Status of present month values

20,22 2901 Status of previous month values

20,22 2902 Status of two months previous values

20,22 2903–2905 Reserved

Frozen Monthly Energy Values

20,22 2906 Real energy, 3-phase IN at start of present month—FMWH3I DECPLE

20,22 2907 Real energy, 3-phase IN at start of previous month—FMWH3I_1M

DECPLE

20,22 2908 Real energy, 3-phase IN at start of two months previ-ous—FMWH3I_2M

DECPLE

20,22 2909–2910 Reserved

20,22 2911 Real energy, 3-phase OUT at start of present month—FMWH3O

DECPLE

20,22 2912 Real energy, 3-phase OUT at start of previous month—FMWH3O_1M

DECPLE

20,22 2913 Real energy, 3-phase OUT at start of two months previ-ous—FMWH30_2M

DECPLE

20,22 2914–2915 Reserved

Consumed Monthly Energy Values

20,22 2916 Consumed real energy, 3-phase IN for present month—CMWH3I

DECPLE

20,22 2917 Consumed real energy, 3-phase IN for previous month—CMWH3I_1M

DECPLE

20,22 2918 Consumed real energy, 3-phase IN for two months previ-ous—CMWH3I_2M

DECPLE

20,22 2919–2920 Reserved

20,22 2921 Consumed real energy, 3-phase OUT for present month—CMWH3O

DECPLE

20,22 2922 Consumed real energy, 3-phase OUT for previous month—CMWH3O_1M

DECPLE

20,22 2923 Consumed real energy, 3-phase OUT for two months previ-ous—CMWH3O_2M

DECPLE

20,22 2924–2925 Reserved

Status of DST Change Frozen/Consumed Energy Values


DNP Object Type


E.9



20,22 2926 Status

DST Change Frozen/Consumed Energy Values

20,22 2927 Real energy, 3 phase IN at DST change—FD_MWH3I DECPLE

20,22 2928 Reactive energy, 3 phase IN at DST change—FD_MVRH3I DECPLE

20,22 2929 Consumed real energy, 3-phase IN at DST change—CD_MWH3I

DECPLE

20,22 2930–2931 Reserved

Status of TOU Season Change Frozen/Consumed Energy Values

20,22 2932 Status

TOU Season Change Frozen/Consumed Energy Values

20,22 2933 Real energy, 3-phase IN at TOU season change—FS_MWH3I DECPLE

20,22 2934 Reactive energy, 3-phase IN at TOU season change—FS_MVRH3I

DECPLE

20,22 2935 Consumed real energy, 3-phase IN at TOU season change—CS_MWH3I

DECPLE

DNP Object Type; Index; Description; Scaling and Deadband

20, 22 2940–2955 SELOGIC Counters 17–32

Load Profile

NOTE: Write a 0–11 to Object 40, 41, index 39 to select between LDP1 and LDP12. See Load Profile on page E.2 for details.

20,22 39 LDP Data Ready

Load Profile Data—Record 1, Channels 1–12

20,22 40 Status

0 Normal record

1 Normal record, Daylight-Saving Time in effect

2 Power loss record

3 Power loss record, Daylight-Saving Time in effect

4 Time set forward

5 Time set forward, Daylight-Saving Time in effect

8 Time set backwards

9 Time set backwards, Daylight-Saving Time in effect

16 Skipped interval

17 Skipped interval, Daylight-Saving Time in effect

32 Test mode record

33 Test mode record, Daylight-Saving Time in effect

20,22 2160 LDAR Setting – LDP. Recorder acquisition rate in seconds

20,22 2161 LDFUNC Setting – LDP Recorder function, enumeration

LDFUNC Value Definition

0 = End of Interval

1 = Average Across Interval

2 = Change Over Interval

3 = Maximum During Interval

4 = Minimum During Interval

20,22 41–43 Record 1 Time—Seconds, Minutes, Hours

20,22 44–46 Record 1 Date—Day, Month, Year

20,22 47–58 Record 1, Channel 1–12 Value Secondary scaled by 100


DNP Object Type


E.10



20,22 2170–2173 Record 1, Channel 13–16 Value Secondary scaled by 100

20,22 59–989 Load Profile Data Record 2–50, Channels 1–12 Secondary scaled by 100

20,22 990–1008 Latest Load Profile Record, Channel 1–12—Follows Analog Output Load Profile Recorder Selection

Secondary scaled by 100

20,22 2174–2369 Load Profile Data Records 2–50, Channels 13–16 Secondary scaled by 100

20,22 2370–2373 Latest Load Profile Data Record, Channels 13–16—Follows Analog Output Load Profile Recorder Selection


Load Profile Most Recent Record Data for All 16 Channels of All 12 Recorders

Recorder 1

20,22 2590 LDAR Setting—LDP Recorder acquisition rate in seconds

20,22 2591 LDFUNC Setting—LDP Recorder function, enumeration

20,22 2592 Status

20,22 2593 Record Time—Seconds

20,22 2594 Minutes

20,22 2595 Hours

20,22 2596 Record Date—Day

20,22 2597 Month

20,22 2598 Year

20,22 2599–2614 Recorder 1—Channels 1–16 Secondary scaled by 100

20,22 2615–2639 Recorder 2 Secondary scaled by 100

20,22 2640–2864 Recorder 3–11 Secondary scaled by 100

20,22 2865–2889 Recorder 12 Secondary scaled by 100

20,22 2890–2899 Reserved

VSSI Data

20,22 1009 VSSI Data Ready

VSSI Data–Record 1

20,22 1010 Record Time—Milliseconds

20,22 1011 Minutes

20,22 1012 Hours

20,22 1013 Record Date—Day

20,22 1014 Month

20,22 1015 Year

20,22 1016–1020 Ia, Ib, Ic, Ig, In (% of nominal) Scaled by 100

20,22 1021–1023 Va, Vb, Vc (L-L if delta) (% of Vbase) Scaled by 100

20,22 1024 Vbase—VA in Volts, Secondary (VAB if Delta) Secondary scaled by 100

20,22 1025 Phase A (AB if delta) State

20,22 1026 Phase B (BC if delta) State

20,22 1027 Phase C (CA if delta) State

20,22 1028 Status

20,22 1029–1959 VSSI Data—Record 2–50


DNP Object Type


E.11



20,22 1970 New VSSI summary

0 No new VSSI Summary

1 New VSSI Summary Available

20,22 1971 Vbase setting value in Volts Secondary scaled by 100

VSSI Summary—Record 1 (oldest)

20,22 1972 Event Type (Enumeration)

DNP Value Definition

0 No Data

1 Dip

2 Swell

3 Interrupt

4 Triggered

5 Power Loss During Event

6 Data Overwrite

11 Dig during ESSI setting change

12 Swell during ESSI setting change

13 Interrupt during ESSI setting change

14 Triggered during ESSI setting change

20,22 1973–1975 Event Time—Milliseconds, Minutes, Hours

20,22 1976–1978 Event Date—Day, Month, Year

20,22 1979–1981 Event Duration—Milliseconds, Minutes, Hours

20,22 1982 Event Magnitude, % Vbase Secondary scaled by 100

20,22 1983 VA Min (% Vbase) (VAB if delta) Secondary scaled by 100

20,22 1984 VA Max (% Vbase) (VAB if delta) Secondary scaled by 100

20,22 1985 VB Min (% Vbase) (VBC if delta) Secondary scaled by 100

20,22 1986 VB Max (% Vbase) (VBC if delta) Secondary scaled by 100

20,22 1987 VC Min (% Vbase) (VCA if delta) Secondary scaled by 100

20,22 1988 VC Max (% Vbase) (VCA if delta) Secondary scaled by 100

20,22 1989 ITIC Region (Enumeration)

ITIC Region Definition

0 No Data

1 No Damage Region

2 Safe Operation Region

3 Prohibited Region

20,22 1990–2151 VSSI Summary—Record 2–10 (newest)

20,22 2152 Vbase Average Time setting value

20,22 2450–2549 VSSI Data Record 1–50 Vbase—VB, VC in Volts, Secondary (VBC, VCA if Delta)


20,22 2550–2579 VSSI Summary Record 1–10 Vbase—VA, VB, VC in Volts, Secondary (VAB, VBC, VCA if Delta)


20,22 2580–2589 Reserved

Analog Inputs

30,32 00–01 IA magnitude and angle, inst. (In 1/100ths of a degree) DECPLA, ANADBA, ANADBM

30,32 02–03 IB magnitude and angle, inst. (In 1/100ths of a degree) DECPLA, ANADBA, ANADBM

30,32 04–05 IC magnitude and angle, inst. (In 1/100ths of a degree) DECPLA, ANADBA, ANADBM


DNP Object Type


E.12



30,32 06–07 IN magnitude and angle, inst. (In 1/100ths of a degree) DECPLA, ANADBA, ANADBM


30,32 36–37 VA magnitude (kV) and angle, inst. (In 1/100ths of a degree) DECPLV, ANADBV, ANADBM

30,32 38–39 VB magnitude (kV) and angle, inst. (In 1/100ths of a degree) DECPLV, ANADBV, ANADBM

30,32 40–41 VC magnitude (kV) and angle, inst. (In 1/100ths of a degree) DECPLV, ANADBV, ANADBM

30,32 42–43 VAB magnitude (kV) and angle, inst. (In 1/100ths of a degree) DECPLV, ANADBV, ANADBM

30,32 44–45 VBC magnitude (kV) and angle, inst. (In 1/100ths of a degree) DECPLV, ANADBV, ANADBM

30,32 46–47 VCA magnitude (kV) and angle, inst. (In 1/100ths of a degree) DECPLV, ANADBV, ANADBM

30,32 48–49 3I0 magnitude and angle (In 1/100ths of a degree) DECPLA, ANADBA, ANADBM

30,32 50–51 I1 magnitude and angle (In 1/100ths of a degree) DECPLA, ANADBA, ANADBM

30,32 52–53 3I2 magnitude and angle (In 1/100ths of a degree) DECPLA, ANADBA, ANADBM


30,32 72–73 3V0 magnitude (kV) and angle (In 1/100ths of a degree) DECPLV, ANADBV, ANADBM

30,32 74–75 V1 magnitude (kV) and angle (In 1/100ths of a degree) DECPLV, ANADBV, ANADBM

30,32 76–77 V2 magnitude (kV) and angle (In 1/100ths of a degree) DECPLV, ANADBV, ANADBM


30,32 84–87 MW A, B, C, and 3-phase DECPLM, ANADBM

30,32 88–91 MVA A, B, C, and 3-phase DECPLM, ANADBM

30,32 92–95 MVAR A, B, C, and 3-phase DECPLM, ANADBM

30,32 96–99 Displacement power factor A, B, C, and 3-phase (In 1/100ths) ANADBM

30,32 100–103 True power factor (with harmoncs) A, B, C and 3-phase (In 1/100ths)

ANADBM

30,32 104 Frequency (In 1/100ths of a Hertz) ANADBM

30,32 105 Reserved

30,32 106–107 Energy—A-phase MWh IN and OUT DECPLM, ANADBM

30,32 108–109 Energy—B-phase MWh IN and OUT DECPLM, ANADBM

30,32 110–111 Energy—C-phase MWh IN and OUT DECPLM, ANADBM

30,32 112–113 Energy—3-phase MWh IN and OUT DECPLM, ANADBM

30,32 114–115 Energy—A-phase MVARh IN and OUT DECPLM, ANADBM

30,32 116–117 Energy—B-phase MVARh IN and OUT DECPLM, ANADBM

30,32 118–119 Energy—C-phase MVARh IN and OUT DECPLM, ANADBM

30,32 120–121 Energy—3-phase MVARh IN and OUT DECPLM, ANADBM

30,32 122–124 Demand—IA, IB, IC magnitudes DECPLA, ANADBA

30,32 125 Demand—IN magnitude DECPLA, ANADBA

30,32 126–129 Demand—A, B, C, and 3-phase demand MW IN DECPLM, ANADBM

30,32 130–133 Demand—A, B, C, and 3-phase demand MVAR IN DECPLM, ANADBM

30,32 134–137 Demand—A, B, C, and 3-phase demand MW OUT DECPLM, ANADBM

30,32 138–141 Demand—A, B, C, and 3-phase demand MVAR OUT DECPLM, ANADBM

30,32 142–145 Demand—MVA A, B, C, and 3-phase IN DECPLM, ANADBM

30,32 146–149 Demand—MVA A, B, C, and 3-phase OUT DECPLM, ANADBM

30,32 150–152 Peak Demand—IA, IB, IC magnitudes DECPLA, ANADBA


DNP Object Type


E.13



30,32 153 Peak Demand—IN magnitude DECPLA, ANADBA

30,32 154–157 Peak Demand—A, B, C, and 3-phase peak demand MW IN DECPLM, ANADBM

30,32 158–161 Peak Demand—A, B, C, and 3-phase peak demand MVAR IN DECPLM, ANADBM

30,32 162–165 Peak Demand—A, B, C, and 3-phase peak demand MW OUT DECPLM, ANADBM

30,32 166–169 Peak Demand—A, B, C, and 3-phase peak demand MVAR OUT DECPLM, ANADBM

30,32 170–173 Peak Demand—MVA A, B, C, and 3-phase IN DECPLM, ANADBM

30,32 174–177 Peak Demand—MVA A, B, C, and 3-phase OUT DECPLM, ANADBM

30,32 178 Leading Reactive Power Delivered—MVR3I_LD DECPLM, ANADBM

30,32 179 Lagging Reactive Power Delivered—MVR3I_LG DECPLM, ANADBM

30,32 180 Leading Reactive Power Received—MVR3O_LD DECPLM, ANADBM

30,32 181 Lagging Reactive Power Received—MVR3O_LG DECPLM, ANADBM

30,32 182–189 Reserved

30 190 Fault type (see Table E.11 for definition) ANADBM

30 191 Fault targets ANADBM

30 192 Fault frequency (In 1/100ths of a Hertz) ANADBM

30 193–195 Fault time in DNP format (high, middle, and low 16 bits) ANADBM

30 196–208 Reserved for additional fault information ANADBM

30,32 209–216 Min/Max—IA, IB, IC, IN magnitudes DECPLA, ANADBA

30,32 217–224 Min/Max Crest Factor—IA, IB, IC, IN magnitudes DECPLA, ANADBA

30,32 225–227 Min—VA, VB, VC (VAB, VBC, VCA if Delta) magnitudes (kV) DECPLV, ANADBV

30,32 228–230 Max—VA, VB, VC (VAB, VBC, VCA if Delta) magnitudes (kV) DECPLV, ANADBV

30,32 231–236 Min/Max Crest Factor—VA, VB, VC (VAB, VBC, VCA if Delta) magnitudes

DECPLV, ANADBV

30,32 237–238 Min/Max—MW 3-phase DECPLM, ANADBM

30,32 239–240 Reserved

30,32 241–242 Min/Max—MVAR 3-phase DECPLM, ANADBM

30,32 243–245 RMS—VAB, VBC, VCA magnitudes (kV) DECPLA, ANADBA, ANADBM

30,32 246 Reserved

30,32 247–250 RMS—IA, IB, IC, IN magnitudes ANADBA, ANADBM

30,32 251–253 RMS—VA, VB, VC magnitudes (kV) DECPLV, ANADBV, ANADBM

30,32 254 Reserved

30,32 255–258 Average Power—MW A-, B-, C-, and 3-phase DECPLM, ANADBM

30,32 259–262 Average Apparent Power—MVAR A-, B-, C-, and 3-phase DECPLM, ANADBM

30,32 263–266 True Apparent (U)—MVA A-, B-, C-, and 3-phase DECPLM, ANADBM

30,32 267 Reserved

30,32 268–271 Supply Line Loss—MW A-, B-, C-, and 3-phase DECPLM, ANADBM

30,32 272–275 Load Line Loss—MW A-, B-, C-, and 3-phase DECPLM, ANADBM

30,32 276–279 Copper Loss—MW A-, B-, C-, and 3-phase DECPLM, ANADBM

30,32 280–283 Iron Loss—MW A-, B-, C-, and 3-phase DECPLM, ANADBM

30,32 284–287 Supply Line Loss—MVR A-, B-, C-, and 3-phase DECPLM, ANADBM

30,32 288–291 Load Line Loss—MVR A-, B-, C-, and 3-phase DECPLM, ANADBM


DNP Object Type


E.14



30,32 292–295 Copper Loss—MVR A-, B-, C-, and 3-phase DECPLM, ANADBM

30,32 296–299 Iron Loss—MVR A-, B-, C-, and 3-phase DECPLM, ANADBM

30,32 300–302 Reserved

30,32 303–306 THD—IA, IB, IC, IN (percent) DECPLM, ANADBM

30,32 307–309 THD—VA, VB, VC (VAB, VBC, VCA if Delta) (percent) DECPLM, ANADBM

30,32 310–312 K-Factor IA, IB, IC ANADBM

30,32 313–316 Distortion Power Ratio DA, DB, DC, D3 ANADBM

30,32 317–319 Reserved

30,32 320–333 Harmonics—IA (2nd … 15th as percent of fundamental) DECPLM, ANADBM

30,32 334 Reserved

30,32 335–348 Harmonics—IB (2nd … 15th as percent of fundamental) DECPLM, ANADBM

30,32 349 Reserved

30,32 350–363 Harmonics—IC (2nd … 15th as percent of fundamental) DECPLM, ANADBM

30,32 364 Reserved

30,32 365–378 Harmonics—IN (2nd … 15th as percent of fundamental) DECPLM, ANADBM

30,32 379 Reserved

30,32 380–393 Harmonics—VA (VAC if Delta) (2nd … 15th as percent of fundamental)

DECPLM, ANADBM

30,32 394 Reserved

30,32 395–408 Harmonics—VB (VBC if Delta) (2nd … 15th as percent of fundamental)

DECPLM, ANADBM

30,32 409 Reserved

30,32 410–423 Harmonics—VC (VCA if Delta) (2nd … 15th as percent of fundamental)

DECPLM, ANADBM

30,32 424–450 Reserved

30,32 451 +3.3 Volt Power Supply DECPLM, ANADBM

30,32 452 +5 Volt Power Supply DECPLM, ANADBM



30,32 455 –1.25 Volt Power Supply DECPLM, ANADBM

30,32 456 –5 Volt Power Supply DECPLM, ANADBM

30,32 457 RTC Battery Voltage DECPLM, ANADBM

30,32 458–462 Reserved

30,32 463 Temperature (In 1/100ths of a degree C) ANADBM

30,32 464–469 Reserved

30,32 470 CTR

30,32 471 CTRN

30,32 472 PTR

30,32 473–479 Reserved

30,32 480–528 Harmonics—IA Magnitudes (2nd . . . 50th) DECPLA, ANADBA

30,32 529–577 Harmonics—IA Angles (2nd . . . 50th) (In 1/100ths of a degree) ANADBM


DNP Object Type


E.15



30,32 578–626 Harmonics—IB Magnitudes (2nd . . . 50th) DECPLA, ANADBA

30,32 627–675 Harmonics—IB Angles (2nd . . . 50th) (In 1/100ths of a degree) ANADBM

30,32 676–724 Harmonics—IC Magnitudes (2nd . . . 50th) DECPLA, ANADBA

30,32 725–773 Harmonics—IC Angles (2nd . . . 50th) (In 1/100ths of a degree) ANADBM

30,32 774–822 Harmonics—IN Magnitudes (2nd . . . 50th) DECPLA, ANADBA

30,32 823–871 Harmonics—IN Angles (2nd . . . 50th) (In 1/100ths of a degree) ANADBM

30,32 872–920 Harmonics—VA Magnitudes (VAB if Delta) (2nd . . . 50th) DECPLV, ANADBV

30,32 921–969 Harmonics–VA Angles (VAB if Delta) (2nd . . . 50th) (In ANADBM

30,32 970–1018 Harmonics—VB Magnitudes (VBC if Delta) (2nd . . . 50th) DECPLV, ANADBV

30,32 1019–1067 Harmonics–VB Angles (VBC if Delta) (2nd . . . 50th) (In 1/100ths of a degree)

ANADBM

30,32 1068–1116 Harmonics—VC Magnitudes (VCA if Delta) (2nd . . . 50th) DECPLV, ANADBV

30,32 1117–1165 Harmonics—VC Angles (VCA if Delta) (2nd . . . 50th) (In 1/100ths of a degree)

ANADBM

30,32 1166–1214 Harmonics—MWA Magnitudes (set to 0 if Delta) (2nd . . . 50th)

DECPLM, ANADBM

30,32 1215–1263 Harmonics—MWB Magnitudes (set to 0 if Delta) (2nd . . . 50th)

DECPLM, ANADBM

30,32 1264–1312 Harmonics—MWC Magnitudes (set to 0 if Delta) (2nd . . . 50th)

DECPLM, ANADBM

30,32 1313–1361 Harmonics—MW3Magnitudes (2nd . . . 50th) DECPLM, ANADBM

30,32 1362–1369 Reserved

30,32 1370–1385 SELOGIC Math Variables (1 . . . 16) DECPLM, ANADBM

30,32 1386–1389 Reserved

30,32 1390–1392 Flicker—PST VA, PST VB, PST VC (if WYE), PST VAB, PST VBC, PST VCA (if Delta)

DECPLM, ANADBM

30,32 1393–1395 Flicker—PLT VA, PLT VB, PLT VC (if WYE), PLT VAB, PLT VBC, PLT VCA (if Delta)

DECPLM, ANADBM

30,32 1396–1397 Seconds until next valid Pst, Plt results DECPLM, ANADBM

30,32 1398–1399 Reserved

30,32 1400–1402 E Voltage Deviation (% of nominal in 1/100ths of a Volt)— Va, Vb, Vc (Vab, Vbc, Vca if Delta)

DECPLM, ANADBM

30,32 1403 E Frequency Deviation (% of nominal in 1/100ths of a Hertz) DECPLM, ANADBM

30,32 1410 I_IMB (Current Imbalance) DECPLE

30,32 1411 V_IMB (Voltage Imbalance) DECPLE

30,32 1412 I_AVE (Average Current, 3-phase) DECPLE

30,32 1413 V_AVE (Average Voltage, 3-phase) DECPLE

30,32 1414–1419 Reserved

30,32 1420–1423 THDG—IA, IB, IC, IN (% of fundamental) DECPLM, ANADBM

30,32 1424–1426 THDG—VA, VB, VC (VAB, VBC, VCA if Delta) (% of fundamental)

DECPLM, ANADBM

30,32 1427–1438 Reserved

Load Profile Most Recent Record Data for All 16 Channels of All 12 Recorders


DNP Object Type


E.16



30,32 1439 LDP Data Ready ANADBM

Recorder 1

30,32 1440 LDAR Setting—LDP Recorder acquisition rate in seconds ANADBM

30,32 1441 LDFUNC Setting—LDP Recorder function, enumeration ANADBM

30,32 1442 Status ANADBM

30,32 1443 Record Time—Seconds ANADBM

30,32 1444 Minutes ANADBM

30,32 1445 Hours ANADBM

30,32 1446 Record Date—Day ANADBM

30,32 1447 Month ANADBM

30,32 1448 Year ANADBM

30,32 1449–1464 Recorder 1, Channels 1–16 ANADBM, Secondary scaled by 100

30,32 1465–1489 Recorder 2

30,32 1490–1714 Recorder 3–11

30,32 1715–1739 Recorder 12

30,32 1740–1749 Reserved

30,32 1750–1774 Latest Load Profile Record—Follows Analog Output Recorder selection


Analog Outputs

40,41 00–31 Remote Analog Outputs 0–31 (RAxx)


40,41 39 Load Profile Recorder Selection

NOTE: Write a 0–11 to Object 40, 41, index 39 to select between LDP1 and LDP12. See Load Profile on page E.2 for details.

LDP Select Date/Time

40,41 40–45 Seconds, Minutes, Hours, Day, Month, Year

40,41 40 Seconds

40,41 41 Minutes

40,41 42 Hours

40,41 43 Day

40,41 44 Month

40,41 45 Year

VSSI Select Date/Time

40,41 46–51 Milliseconds, Minutes, Hours, Day, Month, Year

40,41 46 Milliseconds

40,41 47 Minutes

40,41 48 Hours

40,41 49 Day

40,41 50 Month

40,41 51 Year

Miscellaneous


DNP Object Type


E.17


Distributed Network ProtocolEIA-232 Physical Layer Operation

EIA-232 Physical Layer OperationThe RTS signal may be used to control an external transceiver. The CTS signal is used as a DCD input, indicating when the medium is in use. Transmissions are only initiated if DCD is deasserted. When DCD drops, the next pending outgoing message may be sent once an idle time is satisfied. This idle time is randomly selected between the minimum and maximum allowed idle times (i.e., MINDLY and MAXDLY).

In addition, the SEL-734 monitors received data and treats receipt of data as a DCD indication. This allows RTS to be looped back to CTS in cases where the external transceiver does not support DCD. When the SEL-734 transmits a DNP message, it delays transmitting after asserting RTS by at least the time in the PREDLY setting. After transmitting the last byte of the message, the SEL-734 delays for at least PSTDLY milliseconds before deasserting RTS.

If the PSTDLY time delay is in progress (RTS still high) following a transmission, and another transmission is initiated, the SEL-734 transmits the message without completing the PSTDLY delay and without any preceding PREDLY delay. The RTS/CTS handshaking may be completely disabled by setting PREDLY to OFF. In this case, RTS is forced high and CTS is ignored, with only received characters acting as a DCD indication. The timing is the same as above, but PREDLY functions as if it were set to 0, and RTS is not actually deasserted after the PSTDLY time delay expires.

Ethernet OperationThe SEL-734 DNP LAN/WAN implementation conforms to DNP3 Specification, Vol. 7, Networking—Transporting DNP3 over Local and Wide Area Networks, Version 2.0, Draft H, 15 December 2004. DNP sessions act as listening end points as defined by the DNP LAN/WAN specification listed above.

The DNP-IP response is identical to the serial but requires the following communication specific settings:

50 N/A Time and Date

60 N/A Class Data

80 N/A Internal Indications

112 N/A Virtual Terminal Output Block

113 N/A Virtual Terminal Event Data


DNP Object Type


Table E.7 DNP-IP Specific Settings (Sheet 1 of 2)

Setting Definition RangeDefault Value

EDNP Enable DNP-IP Sessions. Set this value to 0 to disable DNP-IP in the SEL-734.

0–5 0

E.18


Distributed Network ProtocolData-Link Operation

If the UNSOL setting is set to Y, the SEL-734 will transmit unsolicited data when either of the following are true:

➤ Initialization is complete and DNPTR = UDP, or

➤ The master has established a session, if DNPTR = TCP.

Data-Link OperationIt is necessary to make two important decisions about the data-link layer operation. One is how to handle data-link confirmation, the other is how to handle data-link access.

If a highly reliable communications link exists, the data-link access can be disabled altogether, which significantly reduces communications overhead. Otherwise, it is necessary to enable confirmation and determine how many retries to allow and what the data-link time-out should be.

The noisier the communications channel, the more likely a message will be corrupted. Thus, the number of retries should be set higher on noisy channels. Set the data-link time-out long enough to allow for the worst-case response of the master plus transmission time.

When the SEL-734 decides to transmit on the DNP link, it has to wait if the physical connection is in use. The SEL-734 monitors physical connections by using CTS input (treated as a Data Carrier Detect) and monitoring character receipt. Once the physical link goes idle, as indicated by CTS being deasserted and no characters being received, the SEL-734 will wait a configurable amount of time before beginning a transmission. This hold-off time will be a random value between the MINDLY and MAXDLY setting values. The hold-off time is random, which prevents continual collisions resulting from multiple devices waiting to communicate on the network.

DNPNUM DNP TCP and UDP Port.Identifies the TCP and UDP port between the master and the SEL-734.

1–65534 excluding 20, 21, 502, and the TPORT setting.

2000

DNPIPn Master IP Address. Set DNPIP = 0.0.0.0 to accept requests from any DNP-IP address.

zzz.yyy.xxx.www 192.168.0.3

DNPTRn Transport Protocol. Selects between TCP and UDP protocols.

TCP, UDP TCP

DNPUDPn UDP Response Port. Selects the port to which the SEL-734 responds. IF DNPUDP = REQ, the SEL-734 responds to the port number from the master's UDP request.

REQ, 1–65534 2000

Table E.7 DNP-IP Specific Settings (Sheet 2 of 2)

Setting Definition RangeDefault Value

E.19


Distributed Network ProtocolData Access Method

Data Access MethodBased on the capabilities of the system, it is necessary to determine which method you want to use for retrieving data on the DNP connection.

Table E.8 summarizes the main options, listed from least to most efficient, and corresponding key related settings are indicated.

Device ProfileTable E.9 contains the standard DNP3 device profile information. Rather than checkboxes in the example Device Profile in the DNP3 Subset Definitions, only the relevant selections are shown.

Table E.8 Data Access Methods

Data Retrieval Method

DescriptionRelevant SEL-734DNP Settings

Polled Static The master polls forstatic (Class 0) data only

Set ECLASS = 0Set UNSOL = N

Polled Report-by-Exception

The master pollsfrequently for event data and occasionally for static data

Set ECLASS to a non-zero value, Set UNSOL = N

Unsolicited Report-by-Exception

The slave devices sendunsolicited event data to the master and the master occasionally sends integrity polls for static data

Set ECLASS to a non-zero valueSet UNSOL = YSet NUMEVE and AGEEVE according to how often you want to send messages

Quiescent The master neverpolls and relies onunsolicited reports only

Set ECLASS to a non-zero valueSet UNSOL = YSet NUMEVE and AGEEVE according to how often you want to send messages

Table E.9 SEL-734 DNP3 Device Profile (Sheet 1 of 2)

Parameter Value

Vendor name Schweitzer Engineering Laboratories

Device name SEL-734

Highest DNP request level Level 2

Highest DNP response level Level 2

Device function Slave

Notable objects, functions, and/orqualifiers supported

Supports enabling and disabling ofunsolicited reports on a class basis

Maximum data link frame size transmit-ted/received (octets)

292

Maximum data link retries Configurable using DRETRY

Requires data link layer confirmation Configurable using DTIMEO

Maximum application fragment size transmitted/received (octets)

2048

Maximum application layer retries None

Requires application layer confirmation When reporting Event Data

E.20


Distributed Network ProtocolObject Table

Object TableTable E.10 lists the objects and variations with supported function codes and qualifier codes available in the SEL-734. The list of supported objects conforms to the format laid out in the DNP specifications.

Data link confirm time-out Configurable using DTIMEO

Complete application fragment time-out None

Application confirm time-out Configurable using ETIMEO

Complete Application response time-out None

Executes control WRITE binary outputs Always

Executes control SELECT/OPERATE Always

Executes control DIRECT OPERATE Always

Executes control DIRECT OPERATE-NO ACK

Always

Executes control count greater than 1 Never

Executes control Pulse On Always

Executes control Pulse Off Always

Executes control Latch Off Always

Executes control Latch Off Always

Executes control Queue Never

Executes control Clear Queue Never

Reports binary input change events when no specific variation requested

Only time-tagged

Reports time-tagged binary input change events when no specific variation requested

Binary Input change with time

Sends unsolicited responses Configurable using UNSOL

Sends static data in unsolicited responses Never

Default counter object/variation Object 20, Variation 5

Counter roll-over 32 bits

Sends multifragment responses No

Table E.9 SEL-734 DNP3 Device Profile (Sheet 2 of 2)

Parameter Value

Table E.10 SEL-734 DNP Object List (Sheet 1 of 3)

Obj. Var. Description

Request(supported)

Response(may generate)

Funct. Codes (dec)

Qual. Codes (hex)Funct. Codes (dec)

Qual. Codes (hex)

1 0 Binary Input—All Variations 1 0, 1, 6, 7, 8

1 1 Binary Input 1 0, 1, 6, 7, 8, 17, 28 129 0, 1, 17, 28

1 2a Binary Input With Status 1 0, 1, 6, 7, 8, 17, 28 129 0, 1, 17, 28

2 0 Binary Input Change—All Variations 1 6, 7, 8

2 1 Binary Input Change Without Time 1 6, 7, 8 129 17, 28

E.21


Distributed Network ProtocolObject Table

2 2a Binary Input Change With Time 1 6, 7, 8 129, 130 17, 28

2 3 Binary Input Change With Relative Time 1 6, 7, 8 129 17, 28

10 0 Binary Output—All Variations 1 0, 1, 6, 7, 8

10 1 Binary Output

10 2a Binary Output Status 1 0, 1, 6, 7, 8 129 0, 1

12 1 Control Meter Output Block 3, 4, 5, 6 17, 28 129 echo of request

20 0 Binary Counter—All Variations 1, 7, 8 0, 1, 6, 7, 8, 17, 28

20 5a 32-Bit Binary Counter Without Flag 1, 7, 8 0, 1, 6, 7, 8, 17, 28 129 0, 1, 17, 28

20 6 16-Bit Binary Counter Without Flag 1, 7, 8 0, 1, 6, 7, 8, 17, 28 129 0, 1, 17, 28

21 0 Frozen Counter—All Variations 1 0, 1, 6, 7, 8, 17, 28 129 0, 1, 17, 28

21 1a 32-Bit Frozen Counter 1 0, 1, 6, 7, 8, 17, 28 129 0, 1, 17, 28

21 2 16-Bit Frozen Counter 1 0, 1, 6, 7, 8, 17, 28 129 0, 1, 17, 28

21 5 32-Bit Frozen Counter With Time of Freeze 1 0, 1, 6, 7, 8, 17, 28 129 0, 1, 17, 28

21 6 16-Bit Frozen Counter With Time of Freeze 1 0, 1, 6, 7, 8, 17, 28 129 0, 1, 17, 28

22 0 Counter Change Event—All Variations 1 6, 7, 8

22 1 32-Bit Counter Change Event Without Time 1 6, 7, 8 129 17, 28

22 2 16-Bit Counter Change Event Without Time 1 6, 7, 8 129 17, 28

22 5a 32-Bit Counter Change Event With Time 1 6, 7, 8 129, 130 17, 28

22 6 16-Bit Counter Change Event With Time 1 6, 7, 8 129 17, 28

23 0 Frozen Counter Event—All Variations 1 6, 7, 8 129 17, 28

23 1a 32-Bit Frozen Counter Event Without Time 1 6, 7, 8 129, 130 17, 28

23 2 16-Bit Frozen Counter Event Without Time 1 6, 7, 8 129 17, 28

23 5 32-Bit Frozen Counter Event With Time 1 6, 7, 8 129 17, 28

23 6 16-Bit Frozen Counter Event With Time 1 6, 7, 8 129 17, 28

30 0 Analog Input—All Variations 1 0, 1, 6, 7, 8, 17, 28

30 1 32-Bit Analog Input 1 0, 1, 6, 7, 8, 17, 28 129 0, 1, 17, 28

30 2 16-Bit Analog Input 1 0, 1, 6, 7, 8, 17, 28 129 0, 1, 17, 28

30 3 32-Bit Analog Input Without Flag 1 0, 1, 6, 7, 8, 17, 28 129 0, 1, 17, 28

30 4a 16-Bit Analog Input Without Flag 1 0, 1, 6, 7, 8, 17, 28 129 0, 1, 17, 28

32 0 Analog Change Event—All Variations 1 6, 7, 8

32 1 32-Bit Analog Change Event Without Time 1 6, 7, 8 129 17, 28

32 2a 16-Bit Analog Change Event Without Time 1 6, 7, 8 129, 130 17, 28

32 3 32-Bit Analog Change Event With Time 1 6, 7, 8 129 17, 28

32 4 16-Bit Analog Change Event With Time 1 6, 7, 8 129 17, 28

34 1 16-Bit Analog Reporting Deadband 1, 2 0, 1, 6, 7, 8, 17, 28 129 0, 1, 17, 28

34 2 32-Bit Analog Reporting Deadband 1, 2 0, 1, 6, 7, 8, 17, 28 129 0, 1, 17, 28

40 0 Analog Output Status—All Variations 1 0, 1, 6, 7, 8

40 1 32-Bit Analog Output Status 1 0, 1, 6, 7, 8 129 0, 1



Request(supported)


Funct. Codes (dec)


Qual. Codes (hex)

E.22


Distributed Network ProtocolData Map

Data MapAnalog 190 is a 16-bit composite value, where the upper byte is defined as in Table E.11.

The lower byte is defined as in Table E.12.

If Analog 190 is 0, fault information has not been read and the related analogs (191–195) do not contain valid data.

Control Meter Output Blocks (Object 12, Variation 1) are supported. The control meters correspond to the remote bits and other functions, as shown in Table E.13.

40 2a 16-Bit Analog Output Status 1 0, 1, 6, 7, 8 129 0, 1

41 1 32-Bit Analog Output Block 3, 4, 5, 6 17, 28 129 echo of request

41 2a 16-Bit Analog Output Block 3, 4, 5, 6 17, 28 129 echo of request

50 1 Time and Date 1, 2 7, 8 index=0 129 07, quantity=1

50 3 Time and Date—Absolute time at last recorded time. 7, 8 index=0 129 07, quantity=1

51 1 Synchronized Time and Date CTO 07, quantity=1

52 2 Time Delay, Fine 129 07, quantity=1

60 1 Class 0 Data 1 6, 7, 8 17, 28

60 2 Class 1 Data 1, 20, 21 6, 7, 8 17, 28

60 3 Class 2 Data 1, 20, 21 6, 7, 8 17, 28

60 4 Class 3 Data 1, 20, 21 6, 7, 8

80 1 Internal Indications 2 0, 1 index=7

N/A No object required for the following function codes:

13 cold start

14 warm start

23 delay measurement

13, 14, 23

a Default variation



Request(supported)


Funct. Codes (dec)


Qual. Codes (hex)

Table E.11 Event Causes

Value Event Cause

1 Trigger command

2 Reserved

4 Reserved

8 ER element

Table E.12 Fault Type

Value Fault Type

0 Indeterminate

E.23


Distributed Network ProtocolData Map

Exercise caution with multiple remote bit pulses in a single message (i.e., point count > 1), as this may result in some of the pulse commands being ignored and returning an already active status.

Table E.13 Control Field

Index Close (0x4X) Trip (0x8X) Latch On (3) Latch Off (4) Pulse On (1) Pulse Off (2)

0–15 Set Clear Set Clear Pulse Clear

16–18 Pulse OUT101–OUT103

Pulse OUT101–OUT103





19–22 Pulse OUT401–OUT404






23 Reserved Reserved Reserved Reserved Reserved Reserved

24 Pulse RB02 Pulse RB01 Pulse RB02 Pulse RB01 Pulse RB02 Pulse RB01








32–40 Reserved Reserved Reserved Reserved Reserved Reserved

41 Read next meter event

Read next meter event

Read next meter event

No action Read next meter event

No action

42–67 Reserved Reserved Reserved Reserved Reserved Reserved

NOTE: Remote Bit pulses are 25 ms.



Appendix FModbus RTU Communications Protocol

OverviewThis appendix describes Modbus® RTU communications features supported by the SEL-734 Meter communications port.

Complete specifications for the Modbus protocol are available from the Modicon web site at www.modicon.com.

Modbus RTU is a binary protocol that permits communication among a single master device and multiple slave devices. The communication is half duplex; only one device transmits at a time. The master transmits a binary command that includes the address of the desired slave device. All of the slave devices receive the message, but only the slave device with the matching address responds.

The SEL-734 Modbus communication allows a Modbus master device to do the following:

➤ Acquire metering, monitoring, load profile, and event data from the meter.

➤ Control SEL-734 output contacts and remote bits.

➤ Read the SEL-734 self-test status and learn the present condition of all the meter protection elements.

Modbus RTU Communications ProtocolModbus Queries Modbus RTU master devices initiate all exchanges by sending a query. The

query consists of the fields shown in Table F.1.

The SEL-734 SLAVEID setting defines the device address. Set this value to a unique number for each device on the Modbus network. For Modbus communication to operate properly, no two slave devices may have the same address.

A cyclical redundancy check detects errors in the received data. If an error is detected, the meter discards the packet.

Table F.1 Modbus Query Fields

Field Number of Bytes

Slave Device Address 1 byte

Function Code 1 byte

Data Region 0–251 bytes

Cyclical Redundancy Check (CRC) 2 bytes

F.2


Modbus RTU Communications ProtocolModbus RTU Communications Protocol

Modbus Responses The slave device sends a response message after it performs the action requested in the query. If the slave cannot execute the command for any reason, it sends an error response. Otherwise, the slave device response is formatted similarly to the query and includes the slave address, function code, data (if applicable), and a cyclical redundancy check value.

Supported Modbus Function Codes

The SEL-734 supports the Modbus function codes shown in Table F.2.

Modbus Exception Responses

The SEL-734 Meter sends an exception code under the conditions described in Table F.3.

In the event that any of the errors listed in Table F.3 occur, the meter assembles a response message that includes the exception code in the data field. The meter sets the most significant bit in the function code field to indicate to the master that the data field contains an error code, instead of the requested data.

Cyclical Redundancy Check

The SEL-734 calculates a 2-byte CRC value by using the device address, function code, and data fields. It appends this value to the end of every Modbus response. When the master device receives the response, it recalculates the CRC. If the calculated CRC matches the CRC sent by the SEL-734, the master device uses the data received. If there is not a match, the check fails and the message is ignored. The devices use a similar process when the master sends queries.

Table F.2 SEL-734 Meter Modbus Function Codes

Codes Description

01h Read Coil Status

02h Read Input Status

03h Read Holding Registers

04h Read Input Registers

05h Force Single Coil

06h Preset Single Register

08h Loopback Diagnostic Command

10h Preset Multiple Registers

Table F.3 SEL-734 Meter Modbus Exception Codes

Exception Code Error Type Description

01 Illegal Function Code The received function code is either undefined or unsupported.

02 Illegal Data Address The received command contains an unsupported address in the data field.

03 Illegal Data Value The received command contains a value that is out of range.

04 Device Error The SEL-734 Meter is in the wrong state for the requested function.

06 Busy The SEL-734 Meter is unable to process the command at this time because of a busy resource.

08 Memory Error Checksum error on stored data.

F.3



01h Read Coil Status Command

Use function code 01h to read the On/Off status of the selected bits (coils). You can read the status of as many as 2000 bits per query.

Note that the meter coil addresses start at 0 (e.g., Coil 1 is located at address zero). The coil status is packed one coil per bit of the data field. The Least Significant Bit (LSB) of the first data byte contains the starting coil address in the query. The other coils follow towards the high order end of this byte and from low order to high order in subsequent bytes.

To build the response, the meter calculates the number of bytes required to contain the number of bits requested. If the number of bits requested is not evenly divisible by eight, the meter adds one more byte to maintain the balance of bits, padded by zeroes to make an even byte.

The meter responses to errors in the query are shown in Table F.5.

The 01h Read Coil assignments are the same as those in Table F.15.

02h Read Input Status Command

Use function code 02h to read the On/Off status of the selected bits (inputs). You can read the status of as many as 2000 bits per query. Note that the input addresses start at 0 (e.g., Input 1 is located at address zero).

The input status is packed one input per bit of the data field. The LSB of the first data byte contains the starting input address in the query. The other inputs follow towards the high order end of this byte, and from low order to high order in subsequent bytes.

Table F.4 01h Read Coil Status Commands

Bytes Field

Requests from the master must have the following format:

1 byte Slave Address

1 byte Function Code (01h)

2 bytes Address of the First Bit

2 bytes Number of Bits to Read

2 bytes CRC-16

A successful response from the slave will have the following format:



1 byte Bytes of data (n)

n bytes Data

2 bytes CRC-16

Table F.5 Meter Responses to 01h Read Coil Query Errors

Error Error Code ReturnedCommunication Counter Increments

Invalid bit to read Illegal Data Address (02h) Invalid Address

Invalid number of bits to read Illegal Data Value (03h) Illegal Register

Format error Illegal Data Value (03h) Bad Packet Format

F.4



To build the response, the meter calculates the number of bytes required to contain the number of bits requested. If the number of bits requested is not evenly divisible by eight, the meter adds one more byte to maintain the balance of bits, padded by zeroes to make an even byte.

Input numbers are defined in Table F.7.

In each row, the input numbers are assigned from the right-most input to the left-most input (i.e., Input 1 is N and Input 8 is EN). Input addresses start at 0000 (i.e., Input 1 is located at Input Address 0000).


Table F.6 02h Read Input Status Command

Bytes Field




2 bytes Address of the First Bit

2 bytes Number of Bits to Read

2 bytes CRC-16





n bytes Data

2 bytes CRC-16

Table F.7 SEL-734 Meter Inputs

Input Coil Number Input Coil Name Notes

1 IN101

2 IN102

3 IN401 Returns 0 if not installed




Table F.8 Responses to 02h Read Input Query Errors


Invalid bit to read Illegal Data Address (02h) Invalid Address

Invalid number of bits to read Illegal Data Value (03h) Illegal Register


F.5



03h Read Holding Register Command

Use function code 03h to read directly from the Modbus Register Map shown in Table F.23.

You can read a maximum of 125 registers at once with this function code. Most masters use 4X references with this function code. If you are accustomed to 4X references with this function code, for five-digit addressing, add 40001 to the standard database address.


04h Read Input Registers Command

Use function code 04h to read from the Modbus Register Map shown in Table F.23.

You can read a maximum of 125 registers at once with this function code. Most masters use 3X references with this function code. If you are accustomed to 3X references with this function code, for five-digit addressing, add 30001 to the standard database address.

Table F.9 03h Read Holding Register Command

Bytes Field




2 bytes Starting Register Address

2 bytes Number of Registers to Read

2 bytes CRC-16





n bytes Data

2 bytes CRC-16

Table F.10 Responses to 03h Read Holding Register Query Errors


Illegal register to read Illegal Data Address (02h) Invalid Address

Illegal number of registers to read

Illegal Data Value (03h) Illegal Register


Busy Slave is busy with other task (06h)

F.6



The meter responses to errors in the query are shown Table F.12.

05h Force Single Coil Command

Use function code 05h to set or clear a coil. In Table F.13, the command response is identical to the command request.

The coil numbers supported by the SEL-734 can be listed in Table F.14. The physical coils (coils 1–7) are self-resetting. Pulsing a set remote bit clears the remote bit.

Table F.11 04h Read Holding Register Command

Bytes Field




2 bytes Starting Register Address

2 bytes Number of Registers to Read

2 bytes CRC-16





n bytes Data

2 bytes CRC-16

Table F.12 Responses to 04h Read Holding Register Query Errors


Illegal register to read Illegal Data Address (02h) Invalid Address

Illegal number of registers to read

Illegal Data Value (03h) Illegal Register


Busy Slave is busy with other task (06h)

Table F.13 05h Force Single Coil Command

Bytes Field




2 bytes Coil Reference

1 byte Operation Code (FF for bit set, 00 for bit clear)

1 byte Placeholder (00)

2 bytes CRC-16

F.7



Coil addresses start at 0000 (i.e., Coil 1 is located at Coil address 0000). If the meter is disabled or the breaker jumper is not installed, it will respond with error code 4 (Device Error).

In addition to Error Code 4, the meter responses to errors in the query are shown in Table F.15.

06h Preset Single Register Command

The SEL-734 uses this function to allow a Modbus master to write directly to a database register. Refer to the Modbus Register Map in Table F.23 for a list of registers that can be written using this function code. If you are accustomed to 4X references with this function code, for six-digit addressing, add 400001 to the standard database addresses.

In Table F.16, the command response is identical to the command request.


Table F.14 SEL-734 Meter Output Coils (FC05h)

Output Coil Number Output Coil Name Note

1–3 OUT101–OUT103

4–7 OUT401–OUT404 Returns 0 if not installed

8–23 RB01–RB16

24–39 Pulse RB01–Pulse RB16

Table F.15 Responses to 05h Force Singe Coil Query Errors


Invalid bit (coil) number Illegal Data Address (02h) Invalid Address

Illegal bit state requested Illegal Data Value (03h) Illegal FunctionCode/Op Code


Table F.16 06h Preset Single Register Command

Bytes Field




2 bytes Register Address

2 bytes Data

2 bytes CRC-16

Table F.17 Responses to 06h Preset Single Register Query Errors


Illegal register address Illegal Data Address (02h) Invalid Address Illegal Write

Illegal register value Illegal Data Value (03h) Illegal Write


Device Error Invalid Access Level (04h) None

F.8



08h Loopback Diagnostic Command

The SEL-734 uses this function to allow a Modbus master to perform a diagnostic test on the Modbus communications channel and meter. When the subfunction field is 0000h, the meter returns a replica of the received message.


10h Preset Multiple Registers Command

This function code works much like code 06h, except that it allows you to write multiple registers at once, up to 100 per operation. Refer to the Modbus Register Map, Control I/O Commands, in Table F.23 for a list of registers that can be written using this function code. If you are accustomed to 4X references with the function code, for six-digit addressing, simply add 400001 to the standard database addresses.

Table F.18 08h Loopback Diagnostic Command

Bytes Field




2 bytes Subfunction (0000h)

2 bytes Data Field

2 bytes CRC-16




2 bytes Subfunction (0000h)

2 bytes Data Field (identical to data in Master request)

2 bytes CRC-16

Table F.19 Responses to 08h Loopback Diagnostic Query Errors


Illegal subfunction code Illegal Data Value (03h) Illegal Function Code/Op Code


Table F.20 10h Preset Multiple Registers Command (Sheet 1 of 2)

Bytes Field




2 bytes Starting Address

2 bytes Number of Registers to Write

1 byte Bytes of Data (n)

n bytes Data

2 bytes CRC-16

F.9



The meter responses to errors in the query are shown in Table F.21:

Modbus Password Control and Parameter Modification

The SEL-734 parameters MID, TID, Password, and the User Map Registers are settable via Modbus. Any settable parameter or reset that requires a valid password write will time out 15 minutes after the last valid write to any of these restricted registers.

Writing the password for access level change requires the 10h (preset multiple register) command. Changing the password can be done one register at a time. A device error is returned during settings save if the meter is disabled or settings are being changed on another port. Device error is also returned for attempts to write to settable values if the access level has not been changed.

To enable modification of the settable parameters, a valid Access Level E (EAC) password must be written to the password registers through use of function code 10h. Note that changing the password will change the password for all ports.

Once you have written a valid password, change the values by using standard single or multiple register writes (06h or 10h). Until a command is issued to save or discard the settings, the value returned when reading the settable parameter registers is a temporary copy.

To save the modified parameters, write a 0x0001 to the Save Settings register of the Control I/O region. This is the only method that saves the changes.

To discard settings, either write a 0x0001 to the Discard Settings register of the Control I/O region, write a 0x0001 to the Drop Access Level register of the Control I/O region, or wait 15 minutes since last write for access level time-out.




2 bytes Starting Address

2 bytes Number of Registers

2 bytes CRC-16

Table F.21 Responses to 10h Preset Multiple Registers Query Errors


Illegal register to set Illegal Data Address (02h) Invalid Address Illegal Write

Illegal number of registers to set

Illegal Data Value (03h) Illegal Register Illegal Write

Incorrect number of bytes in query data region

Illegal Data Value (03h) Bad Packet Format Illegal Write

Invalid register data value Illegal Data Value (03h) Illegal Write

Table F.20 10h Preset Multiple Registers Command (Sheet 2 of 2)

Bytes Field

F.10



Modbus Sequence Event Recorder Register Operation

To obtain Sequence Event Recorder (SER) records by using the Modbus register map, perform the following steps.

Step 1. Write the date and time for the first desired record to the Start Record Time/Date registers of the SER region of the map.

Step 2. Read the Number of Records Available register to determine how many SER records are available on or after the selected date and time.

Ten records are available for reading from the SER region of the map.

Step 3. Write to the Selected Starting Record register to select additional records from the number available.

For example, if the number of records available is 25, write 11 to the selected starting record to read records 11 to 20.

Modbus Load Profile Register Operation

To read load profile data from the SEL-734 by using the Modbus map, perform the following steps.

Step 1. If reading an SEL-734P that supports up to 12 independent LDP recorders, please refer to Note 1 at the end of Table F.23.

Step 2. Read the Load Profile 1 Name to Load Profile 16 Name registers from the Product Information region of the map.

These names are returned as a NULL terminated ASCII string and provide the human-readable label for the profiled data. If the load profile channel is unused, then the associated label is an empty string.

Step 3. Write the date and time for the first desired record to the Start Record Time/Date registers of the Load Profile region of the map.

As many as 100 records are available on or after the selected date and time. Channels that are not profiling data return a reserved value when read (see Table F.22).

Modbus TCP Modbus TCP is available over Ethernet (Port 1). Determine appropriate ethernet port settings (i.e., IP, Default Router, and Subnet Mask) for your network. Send Modbus requests to Port #502. The SEL-734 Ethernet port supports three simultaneous sessions (see Ethernet on page 10.4).

Table F.22 Modbus Conversion (Sheet 1 of 2)

Conversion DescriptionReserved Value

INT Value ranges from –32767 to 32767 0x8000

INT10 INT with scale factor of 10 (divide by 10 to obtain value) 0x8000



UINT Value ranges from 0 to 65535 0x8000

UINT10 UINT with scale factor of 10 (divide by 10 to obtain value) 0x8000



LONG Value ranges from –2147483647 to 2147483647, most significant word in lower address register 0x80000000

F.11



LONG10 LONG with scale factor of 10 (divide by 10 to obtain value) 0x80000000



BITMAP A bitmapped value

ENUM An enumerated value

STRING A null terminated ASCII string

Table F.23 Modbus Register Map (Sheet 1 of 19)

Address Field Notes Min Max Conversion

Product Information

0–19 0000–0013 FID SEL FID String STRING

20–30 0014–001E MID Meter ID String. Write enabled after valid password entry. See Modbus Password Control and Parameter Modification on page F.9.

STRING

31–41 001F–0029 TID Terminal ID string. Write enabled after valid password entry. See Modbus Password Control and Parameter Modification on page F.9.

STRING

42–46 002A–002E Password Readable once valid pass-word is written. Returns 0 if valid password is not writ-ten. See Modbus Password Control and Parameter Modification on page F.9.

STRING

47–49 002F–0031 Reserved UINT

Load Profile—See Note 1

50 0032 Meter Form 0 = Form 9, 1 = Form 5 ENUM

136–137 0088–0089 CTR Scaled by 10,000 1.0000 6000 LONG

138–139 008A–008B CTRN Scaled by 10,000 1.0000 10000 LONG

140–141 008C–008D PTR Scaled by 10,000 1.0000 10000 LONG

142–175 008E–00AF Reserved

Control I/O Commands Write 0x0001 to perform operation. Read returns Reserved.

176 00B0 Drop Access level

177 00B1 Save Settings See Modbus Password Con-trol and Parameter Modifi-cation on page F.9

178 00B2 Discard

Settings Changes

See Modbus Password Con-trol and Parameter Modifi-cation on page F.9

179 00B3 Reset Communication Counters

Table F.22 Modbus Conversion (Sheet 2 of 2)

Conversion DescriptionReserved Value

F.12



180 00B4 Reset Max/Min Metering Requires valid password write. See Modbus Pass-word Control and Parame-ter Modification on page F.9.

181 00B5 Reset Max/Min Crest Factor Metering Requires valid password write. See Modbus Pass-word Control and Parame-ter Modification on page F.9.

182 00B6 Reset (Peak) Demand Metering Requires valid password write. See Modbus Pass-word Control and Parame-ter Modification on page F.9.

183 00B7 Select Load Profile Recorder See Note 1 for LDP1 or LDP2 selection.

184–255 00B8–00FF Reserved

Note 1: The SEL-734P supports 12 independent load profile recorders, LDP1, LDP2, LDP3, ..., LDP12. Upon power-up, the SEL-734 defaults to and reports LDP1 recorder data. To retrieve LDP2–LDP12 data, write a value of 2, 3, ..., 12 to address 183 before retrieving LDP data. The SEL-734 will return an illegal data value error, 0x03, if the master writes a value other than 1–12. The SEL-734 will return an illegal data address error, 0x02, if the master writes a 2–12 to address 183 and the SEL-734 does not support multiple load profile recorder. Ensure that the master selects the required recorder before reading the SEL-734 with MV-90 because it cannot write to address 183 to change back to LDP1.

Status

Elements Each word resides in the Most Significant Byte of the register. See Meter Word specification for bit definition (see Table 9.4 on page 9.5).

256 0100 Front-Panel LEDS, Row 0 BITMAP

257–332 0101–014C Row 1–Row 76 BITMAP

333–383 014D–017F Reserved

Communication Counters This region contains counters for various communication errors or conditions.

384 0180 Number of messages received Number of messages received

UINT

385 0181 Messages sent to other devices Number of messages sent by the master not addressed to the meter

UINT

386 0182 Invalid address Number or read request messages with invalid re3ad addresses received

UINT

387 0183 Bad CRC Number of messages received with an invalid CRC

UINT

388 0184 UART error Number of messages with UART errors received

UINT

389 0185 Illegal Function code/Op code Number of messages with illegal function codes received (Does not incre-ment with MV90 protocol)

UINT

390 0186 Illegal register Number of messages received that request an operation on an illegal regis-ter

UINT

391 0187 Illegal write Number of invalid write requests received

UINT



F.13



392 0188 Bad packet format Number of messages with illegal size received (Does not increment with MV90 protocol)

UINT

393 0189 Bad packet length Number of times the receive buffer has overflowed

UINT

394–399 018A–018F Reserved UINT

Self Test Status Status is enumerated as 0 = OK, 1 = WARN, 2 = FAIL

400–403 0190–0193 Channel IA, IB, IC, IN Status ENUM

404–406 0194–0196 Channel VA, VB, VC Status ENUM

407–412 0197–019C Power Supply Status: +3.3, +5, +2.5, +3.75, –1.25, –5 V

ENUM

413 019D Clock Battery Status ENUM

414 019E Mainboard Temperature Status ENUM

415 019F RAM Status ENUM

416 01A0 Critical RAM Status ENUM

417 01A1 Program Memory Status ENUM

418 01A2 NONVOL Memory Status ENUM

419 01A3 CT Board Status ENUM

420 01A4 PT Board Status ENUM

421 01A5 Auxiliary Board Status ENUM

422 01A6 Meter Enable Status ENUM

423–431 01A7–01AF Reserved

Real Time Clock Date and Time are write enabled after valid password write.

432 01B0 Time (sec) ss 0 59 UINT

433 01B1 Time (min) mm 0 59 UINT

434 01B2 Time (hour) hh 0 23 UINT

435 01B3 Date (day) day 1 31 UINT

436 01B4 Date (month) month 1 12 UINT

437 01B5 Date (year) year 2000 9999 UINT

438 01B6 Time Source 0 = Internal, 1 = External ENUM

439–447 01B7–01BF Reserved

Sequential Events Recorder Record 1 (Selected) is record closest in date / time to the starting date and time + selected number. See Table F.24 for enumeration.

NOTE: All Min/Max Times include: Seconds (0—59); Minutes (0—59); Hours (0—23)

All Min/Max Dates include: Days (0—31); Months (1—12); Years (2000—9999)

448 01C0 Start Record Time seconds 0 59 UINT

449 01C1 minutes 0 59 UINT

450 01C2 hour 0 23 UINT

451 01C3 Start Record Date day 1 31 UINT

452 01C4 month 1 12 UINT

453 01C5 year 2000 9999 UINT

454 01C6 Selected starting record Read/Writable 0 512 UINT



F.14



455 01C7 Number of records available Records available since start date/time

0 512 UINT

456 01C8 Selected Record type See SER Triggering on page 6.8

ENUM

457 01C9 Selected Record Time seconds, ss.sss 0 59999 UINT1000

458 01CA minutes 0 59 UINT

459 01CB hour 0 23 UINT

460 01CC Selected Record Date day 1 31 UINT

461 01CD month 1 12 UINT

462 01CE year 2000 9999 UINT

463 01CF Selected Record +1 type ENUM

464–469 01D0–01D5 Selected Record +1 Time and Date

470 01D6 Selected Record +2 type ENUM

471–476 01D7–01DC Selected Record +2 Time and Date

477 01DD Selected Record +3 type ENUM

478–483 01DE–01E3 Selected Record +3 Time and Date

484 01E4 Selected Record +4 type ENUM

485–490 01E5–01EA Selected Record +4 Time and Date

491 01EB Selected Record +5 type ENUM

492–497 01EC–01F1 Selected Record +5 Time and Date

498 01F2 Selected Record +6 type ENUM

499–504 01F3–01F8 Selected Record +6 Time and Date

505 01F9 Selected Record +7 type ENUM

506–511 01FA–01FF Selected Record +7 Time and Date

512 0200 Selected Record +8 type ENUM

513–518 0201–0206 Selected Record +8 Time and Date

519 0207 Selected Record +9 type ENUM

520–525 0208–020D Selected Record +9 Time and Date

526–767 020E–02FF Reserved

Metering

Instantaneous Metering Analog values are in secondary.

768 0300 IA Current Magnitude Fundamental UINT1000

769 0301 IA Current Angle –1800 1800 INT10

770 0302 IB Current Magnitude Fundamental UINT1000

771 0303 IB Current Angle –1800 1800 INT10

772 0304 IC Current Magnitude Fundamental UINT1000

773 0305 IC Current Angle –1800 1800 INT10

774 0306 IN Current Magnitude Fundamental UINT1000

775 0307 IN Current Angle –1800 1800 INT10

776 0308 IG Current Magnitude UINT1000

777 0309 IG Current Angle –1800 1800 INT10

778 030A I1 Current Magnitude UINT1000



F.15



779 030B I1 Current Angle –1800 1800 INT10

780 030C 3I2 Current Magnitude UINT1000

781 030D 3I2 Current Angle –1800 1800 INT10

782 030E VA Voltage Magnitude Fundamental VAB if Form 5 UINT100

783 030F VA Voltage Angle VAB if Form 5 –1800 1800 INT10

784 0310 VB Voltage Magnitude Fundamental VBC if Form 5 UINT100

785 0311 VB Voltage Angle VBC if Form 5 –1800 1800 INT10

786 0312 VC Voltage Magnitude Fundamental VCA if Form 5 UINT100

787 0313 VC Voltage Angle VCA if Form 5 –1800 1800 INT10

788 0314 V1 Voltage Magnitude UINT100

789 0315 V1 Voltage Angle –1800 1800 INT10

790 0316 V2 Voltage Magnitude UINT100

791 0317 V2 Voltage Angle –1800 1800 INT10

792 0318 3V0 Voltage Magnitude Reserved if Form 5 UINT10

793 0319 3V0 Voltage Angle Reserved if Form 5 –1800 1800 INT10

794 031A IA Current Magnitude rms UINT1000

795 031B IB Current Magnitude rms UINT1000

796 031C IC Current Magnitude rms UINT1000

797 031D IN Current Magnitude rms UINT1000

798 031E VA Voltage Magnitude rms VAB if Form 5 UINT100

799 031F VB Voltage Magnitude rms VBC if Form 5 UINT100

800 0320 VC Voltage Magnitude rms VCA if Form 5 UINT100

801 0321 Frequency 4500 6500 UINT100

802–803 0322–0323 WA Power Reserved if Form 5 LONG100

804–805 0324–0325 WB Power Reserved if Form 5 LONG100

806–807 0326–0327 WC Power Reserved if Form 5 LONG100

808–809 0328–0329 W3P Power LONG100

810–811 032A–032B VAA Apparent Power Reserved if Form 5 LONG100

812–813 032C–032D VAB Apparent Power Reserved if Form 5 LONG100

814–815 032E–032F VAC Apparent Power Reserved if Form 5 LONG100

816–817 0330–0331 VA3P Apparent Power LONG100

818–819 0332–0333 VARA Reactive Power Reserved if Form 5 LONG100

820–821 0334–0335 VARB Reactive Power Reserved if Form 5 LONG100

822–823 0336–0337 VARC Reactive Power Reserved if Form 5 LONG100

824–825 0338–0339 VAR3P Reactive Power LONG100

826 033A PFA Negative if active energy is received (Quadrants 2 and 3). Reserved if Form 5

–100 100 INT100

827 033B PFB Negative if active energy is received (Quadrants 2 and 3). Reserved if Form 5

–100 100 INT100



F.16



828 033C PFC Negative if active energy is received (Quadrants 2 and 3). Reserved if Form 5

–100 100 INT100

829 033D PF3P Negative if active energy is received (Quadrants 2 and 3).

–100 100 INT100

830 033E VA Deviation AB if Form 5 UINT100

831 033F VB Deviation BC if Form 5 UINT100

832 0340 VC Deviation CA if Form 5 UINT100

833 0341 Frequency Deviation UINT100

834 0342 PST VA VAB if Form 5 UINT100

835 0343 PST VB VBC if Form 5 UINT100

836 0344 PST VC VCA if Form 5 UINT100

837 0345 PLT VA VAB if Form 5 UINT100

838 0346 PLT VB VBC if Form 5 UINT100

839 0347 PLT VC VCA if Form 5 UINT100

840 0348 Seconds until next PST result UINT

841 0349 Seconds until next PLT result UINT

842–1023 034A–03FF Reserved

Energy Metering

Analog values are in secondary except where noted by the primary (Pri) notation which are affected by FP_SCALE, FD_DND, and FP_DECPL.

1024–1029 0400–0405 WhA IN, OUT, Net Reserved if Form 5 LONG100

1030–1035 0406–040B WhB IN, OUT, Net Reserved if Form 5 LONG100

1036–1041 040C–0411 WhC IN, OUT, Net Reserved if Form 5 LONG100

1042–1047 0412–0417 Wh3P IN, OUT, Net LONG100

1048–1051 0418–041B VAhA IN, OUT Reserved if Form 5 LONG100

1052–1055 041C–041F VAhB IN, OUT Reserved if Form 5 LONG100

1056–1059 0420–0423 VAhC IN, OUT Reserved if Form 5 LONG100

1060–1063 0424–0427 VAh3P IN, OUT LONG100

1064–1067 0428–042B VARhA IN, OUT Reserved if Form 5 LONG100

1068–1071 042C–042F VARhB IN, OUT Reserved if Form 5 LONG100

1072–1075 0430–0433 VARhC IN, OUT Reserved if Form 5 LONG100

1076–1079 0434–04375 VARh3P IN, OUT LONG100

1080–1083 0438–043B VARhA IN LAG, LEAD Reserved if Form 5 LONG100

1084–1087 043C–043F VARhA OUT LAG, LEAD Reserved if Form 5 LONG100

1088–1091 0440–0443 VARhB IN LAG, LEAD Reserved if Form 5 LONG100

1092–10953 0444–0447 VARhB OUT LAG, LEAD Reserved if Form 5 LONG100

1096–10997 0448–044B VARhC IN LAG, LEAD Reserved if Form 5 LONG100

1100–1103 044C–044F VARhC OUT LAG, LEAD Reserved if Form 5 LONG100

1104–1107 0450–04531 VARh3P IN LAG, LEAD LONG100

1108–1111 0454–0457 VARh3P OUT LAG, LEAD LONG100

1112–1113 0458–0459 VhA VhAB if Form 5 LONG100

1114–1115 045A–045B VhB VhBC if Form 5 LONG100



F.17



1116–1117 045C–045D VhC VhCA if Form 5 LONG100

1118–1119 045E–045F Vh3P LONG100

1120 0460 Last Reset Time seconds 0 59 UINT

1121 0461 minutes 0 59 UINT

1122 0462 hours 0 23 UINT

1123 0463 Last Reset Date day 1 31 UINT

1124 0464 month 1 12 UINT

1125 0465 year 2000 9999 UINT

1126–1127 0466–0467 IhA LONG100

1128–1129 0468–0469 IhB LONG100

1130–1131 046A–046B IhC LONG100

1132–1133 046C–046D IhN LONG100

1134–1135 046E–046F Ih3P LONG100

1136–1151 0470–047F Reserved

Front-Panel Registers—Primary units affected by FP_SCALE, FP_DND, AND FP_DECPL.

1152–1157 0480–0485 WhA IN, OUT, Net (Pri) Reserved if Form 5 LONG

1158–1163 0486–048B WhB IN, OUT, Net (Pri) Reserved if Form 5 LONG

1164–1169 048C–0491 WhC IN, OUT, Net (Pri) Reserved if Form 5 LONG

1170–1175 0492–0497 Wh3P IN, OUT, Net (Pri) LONG

1176–1179 0498–049B VAhA IN, OUT (Pri) Reserved if Form 5 LONG

1180–1183 049C–049F VAhB IN, OUT (Pri) Reserved if Form 5 LONG

1184–1187 04A0–04A3 VAhC IN, OUT (Pri) Reserved if Form 5 LONG

1188–1191 04A4–04A7 VAh3P IN, OUT (Pri) LONG

1192–1195 04A8–04AB VARhA IN, OUT (Pri) Reserved if Form 5 LONG

1196–1199 04AC–04AF VARhB IN, OUT (Pri) Reserved if Form 5 LONG

1200–1203 04B0–04B3 VARhC IN, OUT (Pri) Reserved if Form 5 LONG

1204–1207 04B4–04B75 VARh3P IN, OUT (Pri) LONG

1208–1211 04B8–04BB VARhA IN LAG, LEAD (Pri) Reserved if Form 5 LONG

1212–1215 04BC–04BF VARhA OUT LAG, LEAD (Pri) Reserved if Form 5 LONG

1216–1219 04C0–04C3 VARhB IN LAG, LEAD (Pri) Reserved if Form 5 LONG

1220–1223 04C4–04C7 VARhB OUT LAG, LEAD (Pri) Reserved if Form 5 LONG

1224–1227 04C8–04CB VARhC IN LAG, LEAD (Pri) Reserved if Form 5 LONG

1228–1231 04CC–04CF VARhC OUT LAG, LEAD (Pri) Reserved Form 5 LONG

1232–1235 04D0–04D3 VARh3P IN LAG, LEAD (Pri) LONG

1236–1239 04D4–04D7 VARh3P OUT LAG, LEAD (Pri) LONG

1240–1241 04D8–04D9 VhA (Pri) VhAB if Form 5 LONG

1242–1243 04DA–04DB VhB (Pri) VhBC if Form 5 LONG

1244–1245 04DC–04DD VhC (Pri) VhCA if Form 5 LONG

1246–1247 04DE–04DF Vh3P (Pri) LONG

1248 04E0 Last Reset Time seconds 0 59 UINT

1249 04E1 minutes 0 59 UINT



F.18



1250 04E2 hours 0 23 UINT

1251 04E3 Last Reset Date day 1 31 UINT

1252 04E4 month 1 12 UINT

1253 04E5 year 2000 9999 UINT

1254–1255 04E6–04E7 IhA LONG100

1256–1257 04E8–04E9 IhB LONG100

1258–1259 04EA–04EB IhC LONG100

1260–1261 04EC–04ED IhN LONG100

1262–1263 04EE–04EF Ih3P LONG100

1264–1279 04F0–04FF Reserved

Present Interval Demand Metering

Analog values are in secondary.

1280 0500 IA Demand UINT1000

1281 0501 IB Demand UINT1000

1282 0502 IC Demand UINT1000

1283 0503 IN Demand UINT1000

1284–1287 0504–0507 WA IN, OUT Reserved if Form 5 LONG100

1288–1291 0508–050B WB IN, OUT Reserved if Form 5 LONG100

1292–1295 050C–050F WC IN, OUT Reserved if Form 5 LONG100

1296–1299 0510–0513 W3P IN, OUT LONG100

1300–1303 0514–0517 VAA IN, OUT Reserved if Form 5 LONG100

1304–1307 0518–051B VAB IN, OUT Reserved if Form 5 LONG100

1308–1311 051C–051F VAC IN, OUT Reserved if Form 5 LONG100

1312–1315 0520–0523 VA3P IN, OUT LONG100

1316–1319 0524–0527 VARA IN LAG, LEAD Reserved if Form 5 LONG100

1320–1323 0528–052B VARA OUT LAG, LEAD Reserved if Form 5 LONG100

1324–1327 052C–052F VARB IN LAG, LEAD Reserved if Form 5 LONG100

1328–1331 0530–0533 VARB OUT LAG, LEAD Reserved if Form 5 LONG100

1332–1335 0534–0537 VARC IN LAG, LEAD Reserved if Form 5 LONG100

1336–1339 0538–053B VARC OUT LAG, LEAD Reserved if Form 5 LONG100

1340–1343 053C–053F VAR3P IN LAG, LEAD LONG100

1344–1347 0540–0543 VAR3P OUT LAG, LEAD LONG100

1348–1351 0544–0547 VARA OUT, IN Reserved if Form 5 LONG100

1352–1355 0548–054B VARB OUT, IN Reserved if Form 5 LONG100

1356–1359 054C–054F VARC OUT, IN Reserved if Form 5 LONG100

1360–1363 0550–0553 VAR3P OUT, IN LONG100



1366 0556 hours 0 23 UINT


1368 0558 month 1 12 UINT



F.19



1369 0559 year 2000 9999 UINT

1370–1535 055A–05FF Reserved

(Peak) Demand Metering Analog values are in secondary.

1536 0600 IA Demand UINT1000

1537 0601 IB Demand UINT1000

1538 0602 IC Demand UINT1000

1539 0603 IN Demand UINT1000

1540–1543 0604–0607 WA IN, OUT Reserved if Form 5 LONG100

1544–1547 0608–060B WB IN, OUT Reserved if Form 5 LONG100

1548–1551 060C–060F WC IN, OUT Reserved if Form 5 LONG100

1552–1555 0610–0613 W3P IN, OUT LONG100

1556–1559 0614–0617 VAA IN, OUT Reserved if Form 5 LONG100

1560–1563 0618–061B VAB IN, OUT Reserved if Form 5 LONG100

1564–1567 061C–061F VAC IN, OUT Reserved if Form 5 LONG100

1568–1571 0620–0623 VA3P IN, OUT LONG100

1572–1575 0624–0627 VARA IN LAG, LEAD Reserved if Form 5 LONG100

1576–1579 0628–062B VARA OUT LAG, LEAD Reserved if Form 5 LONG100

1580–1583 062C–062F VARB IN LAG, LEAD Reserved if Form 5 LONG100

1584–1587 0630–0633 VARB OUT LAG, LEAD Reserved if Form 5 LONG100

1588–1591 0634–0637 VARC IN LAG, LEAD Reserved if Form 5 LONG100

1592–1595 0638–063B VARC OUT LAG, LEAD Reserved if Form 5 LONG100

1596–1599 063C–063F VAR3P IN LAG, LEAD LONG100

1600–1603 0640–0643 VAR3P OUT LAG, LEAD LONG100

1604–1607 0644–0647 VARA IN, OUT Reserved if Form 5 LONG100

1608–1611 0648–064B VARB IN, OUT Reserved if Form 5 LONG100

1612–1615 064C–064F VARC IN, OUT Reserved if Form 5 LONG100

1616–1619 0650–0653 VAR3P IN, OUT LONG100



1622 0656 hours 0 23 UINT


1624 0658 month 1 12 UINT

1625 0659 year 2000 9999 UINT

1626–1791 065A–06FF Reserved

Max/Min Metering Values report FFFFH if reset.



1792 0700 IA Max Current UINT100

1793 0701 IA Max Current Time seconds 0 59 UINT


1795 0703 hours 0 23 UINT



F.20



1796 0704 IA Max Current Date day 1 31 UINT

1797 0705 month 1 12 UINT

1798 0706 year 2000 9999 UINT

1799 0707 IA Min Current UINT100

1800–1805 0708–070D IA Min Current Time and Date UINT

1806 070E IB Max Current UINT100

1807–1812 070F–0714 IB Max Current Time and Date UINT

1813 0715 IB Min Current UINT100

1814–1819 0716–071B IB Min Current Time and Date UINT

1820 071C IC Max Current UINT100

1821–1826 071D–0722 IC Max Current Time and Date UINT

1827 0723 IC Min Current UINT100

1828–1833 0724–0729 IC Min Current Time and Date UINT

1834 072A IN Max Current UINT100

1835–1840 072B–0730 IN Max Current Time and Date UINT

1841 0731 IN Min Current UINT100

1842–1847 0732–0737 IN Min Current Time and Date UINT

1848 0738 VA Max Voltage VAB if Form 5 UINT100

1849–1854 0739–073E VA Max Voltage Time and Date UINT

1855 073F VA Min Voltage VAB if Form 5 UINT100

1856–18618 0740–0745 VA Min Voltage Time and Date UINT

1862 0746 VB Max Voltage VBC if Form 5 UINT100

1863–1868 0747–074C VB Max Voltage Time and Date UINT

1869 074D VB Min Voltage VBC if Form 5 UINT100

1870–1875 074E–0753 VB Min Voltage Time and Date UINT

1876 0754 VC Max Voltage VCA if Form 5 UINT100

1877–1882 0755–075A VC Max Voltage Time and Date UINT

1883 075B VC Min Voltage VCA if Form 5 UINT100

1884–1889 075C–0761 VC Min Voltage Time and Date UINT

1890–1891 0762–0763 MW3P Max Power LONG100

1892–1897 0764–0769 MW3P Max Power Time and Date UINT

1898–1899 076A–076B MW3P Min Power LONG100

1900–1905 076C–0771 MW3P Min Power Time and Date UINT

1906–1907 0772–0773 MVAR3P Max Power LONG100

1908–1913 0774–0779 MVAR3P Max Power Time and Date UINT

1914–1915 077A–077B MVAR3P Min Power LONG100

1916–1921 077C–0781 MVAR3P Min Power Time and Date UINT

1922–1927 0782–0787 Last Reset Time and Date UINT

1928 0788 IA CF Min, Crest Factor UINT100

1929–1934 0789–078E IA CF Min Time and Date UINT

1935 078F IA CF Max, Crest Factor UINT100



F.21



1936–1941 0790–0795 IA CF Max Time and Date UINT

1942 0796 IB CF Min, Crest Factor UINT100

1943–1948 0797–079C IB CF Min Time and Date UINT

1949 079D IB CF Max, Crest Factor UINT100

1950–1955 079E–07A3 IB CF Max Time and Date UINT

1956 07A4 IC CF Min, Crest Factor UINT100

1957–1962 07A5–07AA IC CF Min Time and Date UINT

1963 07AB IC CF Max, Crest Factor UINT100

1964–1969 07AC–07B1 IC CF Max Time and Date UINT

1970 07B2 IN CF Min, Crest Factor UINT100

1971–1976 07B3–07B8 IN CF Min Time and Date UINT

1977 07B9 IN CF Max, Crest Factor UINT100

1978–1983 07BA–07BF IN CF Max Time and Date UINT

1984 07C0 VA CF Min, Crest Factor VAB CF if Form 5 UINT100

1985–1990 07C1–07C6 VA CF Min Time and Date UINT

1991 07C7 VA CF Max, Crest Factor UINT100

1992–1997 07C8–07CD VA CF Max Time and Date UINT

1998 07CE VB CF Min, Crest Factor VBC CF if Form 5 UINT100

1999–2004 07CF–07D4 VB CF Min Time and Date UINT

2005 07D5 VB CF Max, Crest Factor UINT100

2006–2011 07D6–07DB VB CF Max Time and Date UINT

2012 07DC VC CF Min, Crest Factor VCA CF if Form 5 UINT100

2013–2018 07DD–07E2 VC CF Min Time and Date UINT

2019 07E3 VC CF Max, Crest Factor UINT100

2020–2025 07E4–07E9 VC CF Max Time and Date UINT

2026 07EA MW3P CF Max Power UINT100

2027–2032 07EB–07F0 MW3P CF Max Power Time and Date UINT

2033 07F1 MW3P CF Min Power UINT100

2034–2039 07F2–07F7 MW3P CF Min Power Time and Date UINT

2040 07F8 MVAR3P CF Max Power UINT100

2041–2046 07F9–07FE MVAR3P CF Max Power Time and Date UINT

2047 07FF MVAR3P CF Min Power UINT100

2048–2053 0800–0805 MVAR3P CF Min Power Time and Date UINT

2054–2059 0806–080B CF Last Reset Time and Date UINT

2060–2175 080C–087F Reserved

Transformer Line Loss Metering

Analog values are in secondary.

2176–2181 0880–0885 Supply Line Loss A, B, C (W) Reserved if Form 5 LONG100

2182–2183 0886–0887 Supply Line Loss 3P (W) LONG100

2184–2189 0888–088D Supply Line Loss A, B, C (VAR) Reserved if Form 5 LONG100

2190–2191 088E–088F Supply Line Loss 3P (VAR) LONG100



F.22



2192–2197 0890–0895 Load Line Loss A, B, C (W) Reserved if Form 5 LONG100

2198–2199 0896–0897 Load Line Loss 3P (W) LONG100

2200–2205 0898–089D Load Line Loss A, B, C (VAR) Reserved if Form 5 LONG100

2206–2207 089E–089F Load Line Loss 3P (VAR) LONG100

2208–2213 08A0–08A5 CU Watt Loss A, B, C (W) Reserved if Form 5 LONG100

2214–2215 08A6–08A7 CU Watt Loss 3P (W) LONG100

2216–2221 08A8–08AD CU VAR Loss A, B, C (VAR) Reserved if Form 5 LONG100

2222–2223 08AE–08AF CU VAR Loss 3P (VAR) LONG100

2224–2229 08B0–08B5 FE Watt Loss A, B, C (W) Reserved if Form 5 LONG100

2230–2231 08B6–08B7 FE Watt Loss 3P (W) LONG100

2232–2237 08B8–08BD FE VAR Loss A, B, C (VAR) Reserved if Form 5 LONG100

2238–2239 08BE–08BF FE VAR Loss 3P (VAR) LONG100

2240–2245 08C0–08C5 Transformer Loss A, B, C (VA) Reserved if Form 5 LONG100

2246–2247 08C6–08C7 Transformer Loss 3P (VA) LONG100

2248–2295 08C8–08F7 Reserved

Harmonic/Power Quality Metering

2296 08F8 Include interharmonics Note 1 0 1 UINT

2297 08F9 THDG Ia Distortion % UINT

2298 08FA THDG Ib Distortion % UINT

2299 08FB THDG Ic Distortion % UINT

2300 08FC THDG In Distortion % UINT

2301 08FD THDG Va Distortion % THD Vab if Meter Form = 5 UINT

2302 08FE THDG Vb Distortion % THD Vbc if Meter Form = 5 UINT

2303 08FF THDG Vc Distortion % THD Vca if Meter Form = 5 UINT

NOTE: Include interharmonics register may be either 0 or 1. The default is 0.

0: Do not include interharmonics in harmonic magnitude and percent of fundamental quantities.

1: Include interharmonics in harmonic magnitude and percent of fundamental quantities.

2304–2307 0900–0903 THD IA, IB, IC, IN Distortion % 0 100 UINT

2308 0904 THD VA Distortion % THD VAB if Form 5 0 100 UINT

2309 0905 THD VB Distortion % THD VBC if Form 5 0 100 UINT

2310 0906 THD VC Distortion % THD VCA if Form 5 0 100 UINT

2311–2313 0907–0909 IA, IB, IC K-Factor UINT10

2314–2316 090A–090C DA, DB, DC Distortion Power Ratio % Reserved if Form 5 UINT10

2317 090D D3 Distortion Power Ratio % UINT10

2318–2331 090E–091B Harmonic 2–15 IA % UNIT100

2332–2345 091C–0929 Harmonic 2–15 IB % UINT100

2346–2359 092A–0937 Harmonic 2–15 IC % UINT100

2360–2373 0938–0945 Harmonic 2–15 IN % UINT100

2374–2401 0946–0961 Harmonic 2–15 VA % VAB if Form 5 UINT100

2388–2401 0954–0961 Harmonic 2–15 VB % VBC if Form 5 UINT100

2402–2415 0962–096F Harmonic 2–15 VC % VCA if Form 5 UINT100



F.23



2416–2451 0970–0993 Harmonic 16–50 IA % UINT100

2451–2485 0993–09B5 Harmonic 16–50 IB % UINT100

2486–2520 09B6–09D8 Harmonic 16–50 IC % UINT100

2521–2555 09D9–09FB Harmonic 16–50 IN % UINT100

2556–2590 09FC–0A1E Harmonic 16–50 VA % VAB if Form 5 UINT100

2591–2625 0A1F–0A41 Harmonic 16–50 VB % VBC if Form 5 UINT100

2626–2660 0A42–0A64 Harmonic 16–50 VC % VCA if Form 5 UINT100

2661–3071 0971–0BFF Reserved

User Map Registers Provides mapping of selected registers. Writable after valid password write. Read returns current register set. See Modbus Password Control and Parameter Modification on page F.9.

3072–3196 0C00–0C7C Mapped Register 1–125

3197–4095 0C7D–0FFF Reserved

User Map Register Values Provides value of selected mapped registers.

4096–4220 1000–107C Mapped User Register Value 1–125

4221–8191 107D–1FFF Reserved

8192–11297 2000–2C21 Load Profile Records 1–12 Please refer to Load Profile addresses 24579–28993 (see Load Profile on page F.28) for recorders with up to 16 chan-nels supported in firmware versions R130/R530 and later. For details on addresses 8192–11297 that support 12 channels per recorder, please refer to the SEL-734 Instruction Manual that shipped with SEL-734 Meters with firmware versions R129/R529 and earlier.

11298– 12287 2C22–2FFF Reserved

TOU Present Season Data For Present Rate Previous Season, add a value of 1000 to the binary addresses shown for Present Rate. For Present Rate Self Read X, add a value of 2000 to the binary addresses shown for Present Rate. For example, to retrieve “Present Rate Previous Season Rate A MWH Total,” take the Present Rate “Rate A MWH Total” address of 12300–12301, and add 1000: 13300–13301 (3412–3413 Hex).



12288 3000 Present Rate 1 6 UINT

12289 3001 Present Season 1 4 UINT

12290 3002 DST Status 0 1 UINT

12291 3003 Present Day Type 0 9 UINT

12292 3004 Present Self Read Index 0 14 UINT

12293 3005 Valid Self Read Block 0 14 UINT

12294–12299 3006–300B Present Meter Time and Date UINT

12300–12305 300C–3011 Rate A MWH, MVARH, MVAH “Total” LONG

12306–12311 3012–3017 Rate A MWH, MVARH, MVAH “Total” LONG

12312–12317 3018–301D Rate B MWH, MVARH, MVAH “Total” LONG

12318–12323 301E–3023 Rate B MWH, MVARH, MVAH Rcvd LONG

12324–12329 3024–3029 Rate C MWH, MVARH, MVAH “Total” LONG

12330–12335 302A–302F Rate C MWH, MVARH, MVAH Rcvd LONG

12336–12341 3030–3035 Rate D MWH, MVARH, MVAH “Total” LONG

12342–12347 3036–303B Rate D MWH, MVARH, MVAH Rcvd LONG



F.24



12348–12353 303C–3041 Rate E MWH, MVARH, MVAH “Total” LONG

12354–12359 3042–3047 Rate E MWH, MVARH, MVAH Rcvd LONG

12360–12365 3048–304D Rate F MWH, MVARH, MVAH “Total” LONG

12366–12371 304E–3053 Rate F MWH, MVARH, MVAH Rcvd LONG

12372–12377 3054–3059 Total MWH, MVARH Rcvd LONG

12376–12377 3058–3059 Non-Rated MWH “Total” at Peak Demand Reset LONG

12378–12379 305A–305B Non-Rated MWH “Total” since Peak Demand Reset LONG

12380–12381 305C–305D Non-Rated MVAH “Total” at Peak Demand Reset LONG

12382–12383 305E–305F Non-Rated MVAH “Total” since Peak Demand Reset LONG

12384–12385 3060–3061 1st Max MW “Total” Demand LONG

12386–12387 3062–3063 PF at 1st Max MW “Total” Demand LONG1000

12388–12389 3064–3065 1st Max MVAR “Total” Peak Demand LONG

12390–12391 3066–3067 PF at 1st Max MVAR “Total” Peak Demand LONG1000

12392–12393 3068–3069 1st Max MVA “Total” Peak Demand LONG

12394–12395 306A–306B PF at 1st Max MVA “Total” Peak Demand LONG1000

12396–12401 306C–3071 2nd Max MW, MVAR, MVA Total Peak Demand LONG

12402–12407 3072–3077 3rd Max MW, MVAR, MVA Total Peak Demand LONG

12408–12413 3078–307D 4th Max MW, MVAR, MVA Total Peak Demand LONG

12414–12419 307E–3083 5th Max MW, MVAR, MVA Total Peak Demand LONG

12420–12421 3084–3085 Rate A Max MW “Total” Peak Demand LONG

12422–12423 3086–3087 PF at Rate A Max MW “Total” Peak Demand LONG1000

12424–12425 3088–3089 Rate A Max MVAR “Total” Peak Demand LONG

12426–12427 308A–308B PF at Rate A Max MVAR “Total” Peak Demand LONG1000

12428–12429 308C–308D Rate A Max MVA “Total” Peak Demand LONG

12430–12431 308E–308F PF at Rate A Max MVA “Total” Peak Demand LONG1000

12432–12433 3090–3091 Rate B Max MW “Total” Peak Demand LONG

12434–12435 3092–3093 PF at Rate B Max MW “Total” Peak Demand LONG1000

12436–12437 3094–3095 Rate B Max MVAR “Total” Peak Demand LONG

12438–12439 3096–3097 PF at Rate B Max MVAR “Total” Peak Demand LONG1000

12440–12441 3098–3099 Rate B Max MVA “Total” Peak Demand LONG

12442–12443 309A–309B PF at Rate B Max MVA “Total” Peak Demand LONG1000

12444–12445 309C–309D Rate C Max MW “Total” Peak Demand LONG

12446–12447 309E–309F PF at Rate C Max MW “Total” Peak Demand LONG1000

12448–12449 30A0–30A1 Rate C Max MVAR “Total” Peak Demand LONG

12450–12451 30A2–30A3 PF at Rate C Max MVAR “Total” Peak Demand LONG1000

12452–12453 30A4–30A5 Rate C Max MVA “Total” Peak Demand LONG

12454–12455 30A6–30A7 PF at Rate C Max MVA “Total” Peak Demand LONG1000

12456–12457 30A8–30A9 Rate D Max MW “Total” Peak Demand LONG

12458–12459 30AA–30AB PF at Rate D Max MW “Total” Peak Demand LONG1000

12460–12461 30AC–30AD Rate D Max MVAR “Total” Peak Demand LONG

12462–12461 30AE–30AF PF at Rate D Max MVAR “Total” Peak Demand LONG1000



F.25



12464–12465 30B0–30B1 Rate D Max MVA “Total” Peak Demand LONG

12466–12467 30B2–30B3 PF at Rate D Max MVA “Total” Peak Demand LONG1000

12468–12469 30B4–30B5 Rate E Max MW “Total” Peak Demand LONG

12470–12471 30B6–30B7 PF at Rate E Max MW “Total” Peak Demand LONG1000

12472–12473 30B8–30B9 Rate E Max MVAR “Total” Peak Demand LONG

12474–12475 30BA–30BB PF at Rate E Max MVAR “Total” Peak Demand LONG1000

12476–12477 30BC–30BD Rate E Max MVA “Total” Peak Demand LONG

12478–12479 30BE–30BF PF at Rate E Max MVA “Total” Peak Demand LONG1000

12480–12481 30C0–30C1 Rate F Max MW “Total” Peak Demand LONG

12482–12483 30C2–30C3 PF at Rate F Max MW “Total” Peak Demand LONG1000

12484–12485 30C4–30C5 Rate F Max MVAR “Total” Peak Demand LONG

12486–12487 30C6–30C7 PF at Rate F Max MVAR “Total” Peak Demand LONG1000

12488–12489 30C8–30C9 Rate F Max MVA “Total” Peak Demand LONG

12490–12491 30CA–30CB PF at Rate F Max MVA “Total” Peak Demand LONG1000

12492–12509 30CC–30DD 1st Max MW, MVAR, MVA Total Peak Demand Time and Date UINT

12510–12527 30DE–30EF 2nd Max MW, MVAR, MVA Total Peak Demand Time and Date UINT

12528–12545 30F0–3101 3rd Max MW, MVAR, MVA Total Peak Demand Time and Date UINT

12546–12563 3102–3113 4th Max MW, MVAR, MVA Total Peak Demand Time and Date UINT

12564–12581 3114–3125 5th Max MW, MVAR, MVA Total Peak Demand Time and Date UINT

12582–12599 3126–3137 Rate A Max MW, MVAR, MVA Total Peak Demand Time and Date UINT

12600–12617 3138–3149 Rate B Max MW, MVAR, MVA Total Peak Demand Time and Date UINT

12618–12635 314A–315B Rate C Max MW, MVAR, MVA Total Peak Demand Time and Date UINT

12636–12653 315C–316D Rate D Max MW, MVAR, MVA Total Peak Demand Time and Date UINT

12654–12671 316E–317F Rate E Max MW, MVAR, MVA Total Peak Demand Time and Date UINT

12672–12689 3180–3191 Rate F Max MW, MVAR, MVA Total Peak Demand Time and Date UINT

12690–12695 3192–3197 Rate A MW, MVAR, MVA Total Cumulative Demand LONG

12696–12701 3198–319D Rate B MW, MVAR, MVA Total Cumulative Demand LONG

12702–12707 319E–31A3 Rate C MW, MVAR, MVA Total Cumulative Demand LONG

12708–12713 31A4–31A9 Rate D MW, MVAR, MVA Total Cumulative Demand LONG

12714–12719 31AA–31AF Rate E MW, MVAR, MVA Total Cumulative Demand LONG

12720–12725 31B0–31B5 Rate F MW, MVAR, MVA Total Cumulative Demand LONG

12726–12731 31B6–31BB Total MW, MVAR, MVA Cumulative Demand LONG

12732–12735 31BC–31BF Max MW, MVAR Total at last Peak Demand Reset LONG

12736–12737 31C0–31C1 MW Total Demand at min “Total” PF at last Peak Demand Reset LONG

12738–12739 31C2–31C3 MW Total Demand at min “Total” PF since last Peak Demand Reset LONG

12740–12741 31C4–31C5 Min Total PF at last Peak Demand Reset LONG1000

12742–12743 31C6–31C7 Min Total PF since last Peak Demand Reset LONG1000

12744–12745 31C8–31C9 Average Total PF at last Peak Demand Reset LONG1000

12746–12747 31CA–31CB Average Total PF since last Peak Demand Reset LONG1000

12748–12749 31CC–31CD Number of Peak Demand Resets LONG



F.26



12750–12755 31CE–31D3 Max MW Total Peak Demand at last Peak Demand Reset Time and Date UINT

12756–12761 31D4–31D9 Max MVAR Total Peak Demand at last Peak Demand Reset Time and Date UINT

12762–12767 31DA–31DF Min Total PF at last Peak Demand Reset Time and Date UINT

12768–12773 31E0–31E5 Min Total PF since last Peak Demand Reset Time and Date UINT

12774–12779 31E6–31EB Last Peak Demand Reset Time and Date UINT

12780–12781 31EC–31ED Non-Rated MVARH Total at Peak Demand Reset LONG

12782–12783 31EE–31EF Non-Rated MVARH Total since Peak Demand Reset LONG

12784–12785 31F0–31F1 1st Max MW Received Peak Demand LONG

12786–12787 31F2–31F3 PF at 1st Max MW Received Peak Demand LONG1000

12788–12789 31F4–31F5 1st Max MVAR Received Peak Demand LONG

12790–12791 31F6–31F7 PF at 1st Max MVAR Received Peak Demand LONG1000

12792–12793 31F8–31F9 1st Max MVA Received Peak Demand LONG

12794–12795 31FA–31FB PF at 1st Max MVA Received Peak Demand LONG1000

12796–12801 31FC–3201 2nd Max MW, MVAR, MVA Received Peak Demand LONG

12802–12807 3202–3207 3rd Max MW, MVAR, MVA Received Peak Demand LONG

12808–12813 3208–320D 4th Max MW, MVAR, MVA Received Peak Demand LONG

12814–12819 320E–3213 5th Max MW, MVAR, MVA Total Peak Demand LONG

12820–12821 3214–3215 Rate A Max MW Received Peak Demand LONG

12822–12823 3216–3217 PF at Rate A Max MW Received Peak Demand LONG1000

12824–12825 3218–3219 Rate A Max MVAR Received Peak Demand LONG

12826–12827 321A–321B PF at Rate A Max MVAR Received Peak Demand LONG1000

12828–12829 321C–321D Rate A Max MVA Received Peak Demand LONG

12830–12831 321E–321F PF at Rate A MVA Received Peak Demand LONG1000

12832–12833 3220–3221 Rate B Max MW Received Peak Demand LONG

12834–12835 3222–3223 PF at Rate B Max MW Received Peak Demand LONG1000

12836–12837 3224–3225 Rate B Max MVAR Received Peak Demand LONG

12838–12839 3226–3227 PF at Rate B Max MVAR Received Peak Demand LONG1000

12840–12841 3228–3229 Rate B Max MVA Received Peak Demand LONG

12842–12843 322A–322B PF at Rate B MVA Received Peak Demand LONG1000

12844–12845 322C–322D Rate C Max MW Received Peak Demand LONG

12846–12847 322E–322F PF at Rate C Max MW Received Peak Demand LONG1000

12848–12849 3230–3231 Rate C Max MVAR Received Peak Demand LONG

12850–12851 3232–3233 PF at Rate C Max MVAR Received Peak Demand LONG1000

12852–12853 3234–3235 Rate C Max MVA Received Peak Demand LONG

12854–12855 3236–3237 PF at Rate C MVA Received Peak Demand LONG1000

12856–12857 3238–3239 Rate D Max MW Received Peak Demand LONG

12858–12859 323A–323B PF at Rate D Max MW Received Peak Demand LONG1000

12860–12861 323C–323D Rate D Max MVAR Received Peak Demand LONG

12862–12863 323E–323F PF at Rate D Max MVAR Received Peak Demand LONG1000

12864–12865 3240–3241 Rate D Max MVA Received Peak Demand LONG

12866–12867 3242–3243 PF at Rate D MVA Received Peak Demand LONG1000



F.27



12868–12869 3244–3245 Rate E Max MW Received Peak Demand LONG

12870–12871 3246–3247 PF at Rate E Max MW Received Peak Demand LONG1000

12872–12873 3248–3249 Rate E Max MVAR Received Peak Demand LONG

12874–12875 324A–324B PF at Rate E Max MVAR Received Peak Demand LONG1000

12876–12877 324C–324D Rate E Max MVA Received Peak Demand LONG

12878–12879 324E–324F PF at Rate E MVA Received Peak Demand LONG1000

12880–12881 3250–3251 Rate F Max MW Received Peak Demand LONG

12882–12883 3252–3253 PF at Rate F Max MW Received Peak Demand LONG1000

12884–12885 3254–3255 Rate F Max MVAR Received Peak Demand LONG

12886–12887 3256–3257 PF at Rate F Max MVAR Received Peak Demand LONG1000

12888–12889 3258–3259 Rate F Max MVA Received Peak Demand LONG

12890–12891 325A–325B PF at Rate F MVA Received Peak Demand LONG1000

12892–12909 325C–326D 1st Max MW, MVAR, MVA Rcvd Peak Demand Time and Date UINT

12910–12927 326E–327F 2nd Max MW, MVAR, MVA Rcvd Peak Demand Time and Date UINT

12928–12945 3280–328B 3rd Max MW, MVAR, MVA Rcvd Peak Demand Time and Date UINT

12946–12963 3292–32A3 4th Max MW, MVAR, MVA Rcvd Peak Demand Time and Date UINT

12964–12981 32A4–32B5 5th Max MW, MVAR, MVA Rcvd Peak Demand Time and Date UINT

12982–12999 32B6–32C7 Rate A Max MW, MVAR, MVA Rcvd Peak Demand Time and Date UINT

13000–13017 32C8–32D9 Rate B Max MW, MVAR, MVA Rcvd Peak Demand Time and Date UINT

13018–13035 32DA–32EB Rate C Max MW, MVAR, MVA Rcvd Peak Demand Time and Date UINT

13036–13053 32EC–32FD Rate D Max MW, MVAR, MVA Rcvd Peak Demand Time and Date UINT

13054–13071 32FE–330F Rate E Max MW, MVAR, MVA Rcvd Peak Demand Time and Date UINT

13072–13089 3310–3321 Rate F Max MW, MVAR, MVA Rcvd Peak Demand Time and Date UINT

13090–13287 3322–33E7 Reserved

13288–14089 33E8–37CF

14090–14286 370A–37CE Reserved

14287 37CF Self-Read Selection Index Read/Write 0 29 UINT

14288–15089 37D0–3AF1 Present Rate (Self Read X) UINT

15090–16383 3AF2–3FFF Reserved

16384–16432 4000–4030 Harmonic 2–50 IA Mag UINT1000

16433–16481 4031–4061 Harmonic 2–50 IB Mag UINT1000

16482–16530 4062–4092 Harmonic 2–50 IC Mag UINT1000

16531–16579 4093–40C3 Harmonic 2–50 IN Mag UINT1000

16580–16677 40C4–4125 Harmonic 2–50 VA Mag VAB if Form 5 LONG1000

16678–16775 4126–4187 Harmonic 2–50 VB Mag VBC if Form 5 LONG1000

16776–16873 4188–41E9 Harmonic 2–50 VC Mag VCA if Form 5 LONG1000

16874–16922 41EA–421A Harmonic 2–50 IA Ang –180 180 INT

16923–16971 421B–424B Harmonic 2–50 IB Ang –180 180 INT

16972–17020 424C–427C Harmonic 2–50 IC Ang –180 180 INT

17021–17069 427D–42AD Harmonic 2–50 IN Ang –180 180 INT



F.28



17070–17118 42AE–42DE Harmonic 2–50 VA Ang VAB if Form 5 –180 180 INT

17119–17167 42DF–430F Harmonic 2–50 VB Ang VBC if Form 5 –180 180 INT

17168–17216 4310–4340 Harmonic 2–50 VC Ang VCA if Form 5 –180 180 INT

17217–17314 4341–43A2 Harmonic 2–50 Power A-Phase Reserved if Form 5 LONG10

17315–17412 43A3–4404 Harmonic 2–50 Power B-Phase Reserved if Form 5 LONG10

17413–17510 4405–4466 Harmonic 2–50 Power C-Phase Reserved if Form 5 LONG10

17511–17608 4467–44C8 Harmonic 2–50 Power 3-Phase LONG10

17609–24575 44C9–5FFF Reserved

Load Profile All times include: Seconds (0–59); Minutes (0–59); Hours (0–23). All dates include: Days (0–31; Months (1–12); Years (2000–9999).

24576 6000 Select Load Profile Recorder See Note 1 UINT

24577 6001 Load Profile Update Rate, LDAR Rate is in seconds 3 3600 UINT

24578 6002 Load Profile Channel Function, LDFUNC enumeration is defined as follows:

0 = End of Interval

1 = Average

2 = Change Over Interval

3 = Max in Interval

4 = Min in Interval

Load Profile Channel Function

0 4 ENUM

24579–24591 6003–600F Reserved

24592–24598 6010–6016 Load Profile Value 1 Name STRING

24599–24605 6017–601D Load Profile Value 2 Name STRING

24606–24612 601E–6024 Load Profile Value 3 Name STRING

24613–24619 6025–602B Load Profile Value 4 Name STRING

24620–24626 602C–6032 Load Profile Value 5 Name STRING


24634–24640 603A–6040 Load Profile Value 7 Name STRING


24648–24654 6048–604E Load Profile Value 9 Name STRING

24655–24661 604F–6055 Load Profile Value 10 Name STRING

24662–24668 6056–605C Load Profile Value 11 Name STRING

24669–24675 605D–6063 Load Profile Value 12 Name STRING

24676–246682 6064–606A Load Profile Value 13 Name STRING

24683–24689 606B–6071 Load Profile Value 14 Name STRING


24697–24703 6079–607F Load Profile Value 16 Name STRING

24704–25087 6080–61FF Reserved

25088 6200 Starting Record Time sec 0 59 UINT

25089 6201 min 0 59 UINT

25090 6202 hour 0 23 UINT



F.29



25091 6203 Starting Record Date day 1 31 UINT

25092 6204 month 1 12 UINT

25093 6205 year 2000 9999 UINT

25094 6206 Record 1 Status ENUM

25095–25100 6206–620C Record 1 Time and Date UINT

25101–25102 620D–620E Value 1 LONG100

25103–25104 620F–6210 Value 2 LONG100

25105–25106 6211–6212 Value 3 LONG100

25107–25108 6213–6214 Value 4 LONG100

25109–25110 6215–6216 Value 5 LONG100

25111–25112 6217–6218 Value 6 LONG100

25113–25114 6219–621A Value 7 LONG100

25115–25116 621B–621C Value 8 LONG100

25117–25118 621D–621E Value 9 LONG100

25119–25120 621F–6220 Value 10 LONG100

25121–25122 6221–6222 Value 11 LONG100

25123–25124 6223–6224 Value 12 LONG100

25125–25126 6225–6226 Value 13 LONG100

25127–25128 6227–6228 Value 14 LONG100

25129–25130 6229–622A Value 15 LONG100

25131–25132 622B–622C Value 16 LONG100

25133 6622D Record 2 Status ENUM

25134–25139 622E–6233 Record 2 Time and Date UINT

25140–25171 6234–6253 Record 2 Value 1–16 LONG100

25172 6254 Record 3 Status ENUM

25173–25178 6255–625A Record 3 Time and Date UINT

25179–25210 625C–627A Record 3 Value 1–16 LONG100

25211–28993 627B–7141 Record 4–100 with Status, Time, and Date, and Value 1–16

ENUM, UINT, LONG100

28993–65535 7142–FFFF Reserved



F.30



Table F.24 lists the sequence of events enumerations noted in Table F.23.

Table F.25 lists the load profile status enumerations noted in the Load Profile portion of Table F.23.

Table F.26 lists the load profile record status bits noted in the Load Profile portion of Table F.23.

Table F.24 Sequence of Event Enumerations

Enumeration Description

0 Meter settings have changed

1 Power restored

2 Power loss

3 Time change, manual set occurred

4 Daylight-Saving Time, automatic set occurred

0x1yyy A meter element has changed, element number yyy. See Meter Word Bits (Used in SELogic Control Equations) on page 9.2. These elements are associated with SER settings SER1, SER2 and SER3. The element is deasserted.

0x2yyy A meter element has changed, element number yyy. See Meter Word Bits (Used in SELogic Control Equations) on page 9.2. These elements are associated with SER settings SER1, SER2 and SER3. The element is asserted.

0x8000 Invalid record.

Table F.25 Load Profile Status Enumeration

Enumeration Description

0 Normal Record

1 Normal Record, Daylight-Saving Time in Effect

2 Power Loss Record

3 Power Loss Record, Daylight-Saving Time in Effect

4 Time Set Forward

5 Time Set Forward, Daylight-Saving Time in Effect

8 Time Set Backwards

9 Time Set Backwards, Daylight-Saving Time in Effect

16 Skipped Interval

17 Skipped Interval, Daylight-Saving Time in Effect

32 Test Mode Record

33 Test Mode Record, Daylight-Saving Time in Effect

Table F.26 Load Profile Record Status Bits

Bit Meaning

0 (LSB)a

a LSB: Least Significant Bit

Daylight-Saving Time in Effect

1 Power Loss

2 Time Set Forward


4 Skipped Interval

5 Test Mode Record

F.31



Combine one or more status bits from Table F.25 to create a custom response as exemplified in Figure F.1 and Table F.27.

Figure F.1 Example Decimal Enumeration

Table F.27 Example Load Profile Status Enumeration

Decimal Enumeration Description

0 Normal Record

1 Normal Record, Daylight-Saving Time in Effect

2 Power Loss Record

3 Power Loss Record, Daylight-Saving Time in Effect

4 Time Set Forward

5 Time Set Forward, Daylight-Saving Time in Effect


9 Time Set Backwards, Daylight-Saving Time in Effect

16 Skipped Interval

17 Skipped Interval, Daylight-Saving Time in Effect

32 Test Mode Record

33 Test Mode Record, Daylight-Saving Time in Effect

Bit 5

Dec = 33

Dec = 5

Bit 4 Bit 3 Bit 2 Bit 1 Bit 0

TMRec SkpInt TSBw TSFw PLoss DST



Appendix GMIRRORED BITS Communications

OverviewMIRRORED BITS® is a direct meter-to-meter communications protocol that allows meters to exchange information quickly and securely, and with minimal expense.

The SEL-734 supports two MIRRORED BITS channels, differentiated by the channel specifiers A and B. Bits transmitted are called TMB1x through TMB8x, where x is the channel specifier (e.g., A or B), and are controlled by the corresponding SELOGIC® control equations. Bits received are called RMB1x through RMB8x and are usable as inputs to any SELOGIC control equations. Channel status bits are called ROKx, RBADx, CBADx and LBOKx and are also usable as inputs to any SELOGIC control equations. Further channel status information is available via the COM command. If both the A and B MIRRORED BITS channels are active, the COM A or COM B commands must be used to distinguish which channel is displayed.

OperationPort Connections See Figure 10.7 on page 10.7.

Message Formatting MIRRORED BITS communications protocol options include MBA and MBB for standard MIRRORED BITS communications and MB8A/MB8B for special message formats required with radios and some CSU/DSU devices.

MIRRORED BITS communications messages consist of four characters or bytes. Each byte is made up of a start bit, six data bits, one parity bit, and one or two stop bits. The MBA/MBB settings protocol includes one stop bit, for a total of nine bits per character. The MB8n protocol setting includes two stop bits, for a total of 10 bits per character. Use the MB8n setting with communication channel equipment that counts bits and requires a 10-bit character.

Message Transmission

All messages are transmitted without idle bits between characters. Idle bits are allowed between messages.

➤ At 4800 baud, one message is transmitted each 1/2 power system cycle.

➤ At 9600 baud, one message is transmitted each 1/4 power system cycle.

➤ At 19200 and 38400 baud, one message is transmitted each 1/4 power system cycle for the SEL-734.

G.2


MIRRORED BITS CommunicationsOperation

Message Decoding and Integrity Checks

The meter will deassert a user-accessible flag per channel (hereafter called ROKx) upon failing any of the following received-data checks:

➤ Parity, framing, or overrun errors.

➤ Receive data redundancy error.

➤ Receive message identification error.

➤ No message received in the time three messages have been sent.

While ROKx is not asserted, the meter will:

1. Prevent new data from being transferred to the pickup/dropout security counters described later. Instead, the meter will send one of the following user selectable values (hereafter called default values) to the security counter inputs:

➢ 1

➢ 0

➢ The last valid value

You will be allowed to select one of the default values for each RMB.

2. Enter the synchronization process described below.

The meter will assert ROKx only after successful synchronization (as described below) and two consecutive messages pass all of the data checks described above. After ROKx is reasserted, received data may be delayed while passing through the security counters described below.

Transfer of received data to RMB1x–RMB8x is supervised by 8 user-programmable pickup/dropout security counters settable from 1 (allow every occurrence to pass) to at least 8 (require 8 consecutive occurrences to pass). The pickup and dropout security count settings are separate.

A pickup/dropout security counter operates identically to a pickup/dropout timer, except that it is set in counts of received messages instead of time. An SEL-734 communicating with another SEL-734 sends and receives MIRRORED BITS messages 4 times per power system cycle. Therefore, a security counter set to 2 counts will delay by about a half power system cycle.

Things become more complicated when two meters of different processing rates are connected via MIRRORED BITS, as in the case of an SEL-321 communicating with an SEL-734. The SEL-321 processes power system information each 1/8 power system cycle, but processes the pickup/dropout security counters as messages are received. Because the SEL-321 is receiving messages from the SEL-734, it will receive a message per 1/4-cycle processing interval. So a counter set to two will again delay by about a half cycle. However, in that same example, a security counter set to two on the SEL-734 will delay by 1/4-cycle, because the SEL-734 is receiving new MIRRORED BITS messages each 1/8 cycle from the SEL-321.

Synchronization When a node detects a communications error, it deasserts ROKx and transmits an attention message, which includes the TX_ID setting for that node.

When a node receives an attention message, it checks whether its TX_ID is included.

If its own TX_ID is included along with at least one other TX_ID, the node transmits data.

G.3


MIRRORED BITS CommunicationsOperation

If its own TX_ID is not included, the node deasserts ROKx, includes its TX_ID in the attention message, and transmits the new attention message.

If its own TX_ID is the only TX_ID included, the meter assumes the message is corrupted unless the loopback mode has been enabled. If loopback is not enabled, the node deasserts ROKx and transmits the attention message with its TX_ID included. If loopback is enabled, the meter transmits data.

In summary, when a node detects an error, it transmits an attention message until it receives an attention message with its own TX_ID included. If three or four meters are connected in a ring topology, the attention message will go all the way around the loop until it is received by the originating node. The message then dies, and data transmission resumes.

This method of synchronization allows the meters to reliably determine which byte is the first byte of the message. It also forces unsynchronized UARTs to become resynchronized. On the down side, this method takes down the entire loop for a receive error at any node in the loop. This decreases availability. It also makes one-way communications impossible.

Loopback Testing Use the LOOP command to enable loopback testing.

While in loopback mode, ROKx is deasserted, and another user-accessible flag, LBOKx, asserts and deasserts according to received data checks.

Channel Monitoring Based on the results of data checks described above, the meter will collect information regarding the 255 most recent communications errors. Each record will contain at least the following fields:

➤ Dropout Time/Date

➤ Pickup Time/Date

➤ Time elapsed during dropout

➤ Reason for dropout (See Message Decoding and Integrity Checks on page G.2)

Use the COM command to generate a long or summary report of the communications errors.

There is only a single record for each outage, but an outage can evolve. For example, the initial cause could be a data disagreement, but the outage can be perpetuated by framing errors. If the channel is presently down, the COM record will only show the initial cause, but the COM summary will display the present cause of failure.

When the duration of an outage exceeds a user-settable threshold, the meter asserts a user-accessible flag called RBADx.

You would typically combine RBADx with other alarm conditions through use of SELOGIC control equations.

When channel unavailability exceeds a user-settable threshold, the meter asserts a user-accessible flag called CBADx.

You would typically combine CBADx with other alarm conditions through use of SELOGIC control equations.

G.4


MIRRORED BITS CommunicationsMIRRORED BITS Protocol for Pulsar 9600 Baud Modem

MIRRORED BITS Protocol for Pulsar 9600 Baud ModemYou can indicate that a Pulsar MBT modem is to be used by responding with an entry of MBT to the RTS/CTS setting prompt. When you select MBT, the baud rate setting will be limited to 9600 baud.

The MIRRORED BITS protocol compatible with the Pulsar MBT9600 modem is identical to the standard MIRRORED BITS protocol, with the following exceptions:

➤ The meter injects a delay (idle time) between messages. The length of the delay is one meter processing interval.

➤ The meter resets RTS (to a negative voltage at the EIA-232 connector) for MIRRORED BITS communications through use of this specification. The meter sets RTS (to a positive voltage at the EIA-232 connector) for MIRRORED BITS communications, using the R6 or original R version of MIRRORED BITS.

SettingsProtocol(SEL,LMD,DNP,DNPE,MBA,MBB,MB8A,MB8B) PROTO = MB8A ?

Set PROTO = MBA or MB8A to enable the MIRRORED BITS protocol channel A on this port. Set PROTO = MBB or MB8B to enable the MIRRORED BITS protocol channel B on this port. The standard MIRRORED BITS protocols MBA and MBB use a 7-data bit format for data encoding. The MB8 protocols MB8A and MB8B use an 8-data bit format, which allows MIRRORED BITS to operate on communication channels requiring an 8-data bit format. For the remainder of this section, PROTO = MBA is assumed.

Baud Rate(300-38400) SPEED = 9600 ?

Use the SPEED setting to control the rate at which the MIRRORED BITS messages are transmitted, in power system cycles (~), based on Table G.1:

Enable Hardware Handshaking(Y,N,MBT) RTSCTS= N ?

Use the MBT option if you are using a Pulsar MBT9600 baud modem. With this option set, the meter will transmit a message every 1/2 power system cycle and the meter will deassert the RTS signal on the EIA-232 connector. Also, the meter will monitor the CTS signal on the EIA-232 connector, which the modem will deassert if the channel has too many errors. The modem uses the meter RTS signal to determine whether the new or old MIRRORED BITS protocol is in use.

NOTE: The MBT mode will not work with PROTO = MB8A or MB8B.

NOTE: An idle processing interval guarantees at least 19 idle bits at 9600 baud in an SEL-734 Meter with the system frequency at 65 Hz.

Table G.1 Using the SPEED Setting to Control MIRRORED BIT Rates

SPEED SEL-321 SEL-734

38400 1 message per 1/8 cycle 1 message per 4 ms




G.5


MIRRORED BITS CommunicationsSettings

Seconds to Mirrored Bits Rx Bad Pickup(1-10000) RBADPU= 60 ?

Use the RBADPU setting to determine how long a channel error must last before the meter element RBADA is asserted. RBADA is deasserted when the channel error is corrected. RBADPU is accurate to ±1 second.

PPM Mirrored Bits Channel Bad Pickup(1-10000) CBADPU= 1000 ?

Use the CBADPU setting to determine the ratio of channel down time to the total channel time before the meter element CBADA is asserted. The times used in the calculation are those that are available in the COM records. See the COM command in the instruction manual for a description of the COM records.

Mirrored Bits Receive Identifier(1-4) RXID = 1 ? Mirrored Bits Transmit Identifier(1-4) TXID = 2 ?

Set the RX_ID of the local meter to match the TX_ID of the remote meter. For example, in the three-terminal case, where Meter X transmits to Meter Y, Meter Y transmits to Meter Z, and Meter Z transmits to Meter X (see Table G.2).

Mirrored Bits Receive Default State(string of 1s, 0s or Xs)

87654321

RXDFLT=XXXXXXXX ?

Use the RXDFLT setting to determine the default state the MIRRORED BITS should use in place of received data if an error condition is detected. The setting is a mask of 1s, 0s, and/or Xs (for RMB1A–RMB8A), where X represents the most recently received valid value.

Mirrored Bits RMB_ Pickup Debounce msgs(1-8) RMB1PU= 1 ? Mirrored Bits RMB_ Dropout Debounce msgs(1-8) RMB1DO= 1 ? Mirrored Bits RMB_ Pickup Debounce msgs(1-8) RMB2PU= 1 ? Mirrored Bits RMB_ Dropout Debounce msgs(1-8) RMB2DO= 1 ? Mirrored Bits RMB_ Pickup Debounce msgs(1-8) RMB3PU= 1 ? Mirrored Bits RMB_ Dropout Debounce msgs(1-8) RMB3DO= 1 ? Mirrored Bits RMB_ Pickup Debounce msgs(1-8) RMB4PU= 1 ? Mirrored Bits RMB_ Dropout Debounce msgs(1-8) RMB4DO= 1 ? Mirrored Bits RMB_ Pickup Debounce msgs(1-8) RMB5PU= 1 ? Mirrored Bits RMB_ Dropout Debounce msgs(1-8) RMB5DO= 1 ? Mirrored Bits RMB_ Pickup Debounce msgs(1-8) RMB6PU= 1 ? Mirrored Bits RMB_ Dropout Debounce msgs(1-8) RMB6DO= 1 ? Mirrored Bits RMB_ Pickup Debounce msgs(1-8) RMB7PU= 1 ? Mirrored Bits RMB_ Dropout Debounce msgs(1-8) RMB7DO= 1 ? Mirrored Bits RMB_ Pickup Debounce msgs(1-8) RMB8PU= 1 ? Mirrored Bits RMB_ Dropout Debounce msgs(1-8) RMB8DO= 1 ?

Supervise the transfer of received data (or default data) to RMB1A–RMB8A with the MIRRORED BITS pickup and dropout security counters. Set the pickup and dropout counters individually for each bit.

Table G.2 Matching RX_ID of Local Meter to TX_ID of Remote Meter

TX_ID RX_ID

Meter X 1 3

Meter Y 2 1

Meter Z 3 2



Appendix HAnalog Quantities

The analog quantities are separated into several categories with similar context. Use these quantity names to meter, monitor in load profile, etc.

The Usage columns define which data output methods have access to each data point.

➤ MET = Serial port METER commands

➤ HMI = Front-panel METER commands

➤ LDP = Load Profile Recorder

➤ DP = Display Points

➤ Logic = SELOGIC® analog comparisons (e.g., “SV01 := IN > 10.0”)

➤ DNP = DNP3

➤ Modbus = Modbus® RTU

➤ CASC = Compressed ASCII

➤ FM = SEL Fast Meter

➤ AO = Analog Outputs

➤ DAT = Serial port DATE/TIME commands

➤ COU = Serial port COUNT commands

➤ MAT = Serial port MATH command

➤ Pri = Primary values, affected by scaling settings, PTR, and CTR settings.

➤ Sec = Secondary values

➤ (5) = Form 5 delta-connected meters only

➤ (9) = Form 9 wye-connected meters only

➤ MAG = Magnitudes updated every 25 ms with fundamental data

➤ ANG = Angles updated every 25 ms

➤ RMS or AVG = Magnitudes updated every 1 s with 8 kHz data

H.2


Analog Quantities

Table H.1 Instantaneous and RMS Quantities (Sheet 1 of 3)

Name Description Units

Usage

MET (Pri)

HMI (Pri)

LDP (Sec)

DP (Pri)

Logic (Sec)

DNP (Pri)

Modbus (Sec)

FM(Pri)

AO (Pri)

Ix_MAG Current, x-phase, mag. where

x = A, B, C, or N

Amps x x x x x x x x x

Ix_ANG Current, x-phase, ang. where

x = A, B, C, or N

degrees x x x x x x x x

Ix_RMS Current, x-phase RMS mag. where

x = A, B, C, or N

Amps x x x x x x x x

IG_MAG Current, neutral or calculated-residual (auto switching), mag.

Amps x x x x x x x

IG_ANG Current, neutral or calculated-residual (auto switching), ang.

degrees x x x x x x

I1_MAG Current, positive-seq., mag. Amps x x x x x x x x x

I1_ANG Current, positive-seq., ang. degrees x x x x x x x x

3I0_MAG Current, 3-phase zero-seq., mag. Amps x x x x

3I0_ANG Current, 3-phase zero-seq., ang. degrees x x x x

3I2_MAG Current, 3-phase neg.-seq., mag. Amps x x x x x x x x x

3I2_ANG Current, 3-phase neg.-seq., ang. degrees x x x x x x x x

Vx_MAG (9) Voltage, x-phase-to-neutral mag. where x = A, B, C, or N

Volts x x x x x x x x x

Vx_ANG (9) Voltage, x-phase, ang.where

x = A, B, C, or N

degrees x x x x x x x x

Vx_RMS (9) Voltage, x-phase RMS mag. where

x = A, B, C, or N

Volts x x x x x x x x

Vx_MAG Voltage, x-phase mag. where

x = AB, BC, or CA

Volts x x x x x x xa x x

Vx_ANG Voltage, x-phase, ang. where

x = AB, BC, or CA

degrees x x x x x xa x x

Vx_RMS Voltage, x RMS mag. where

x = AB, BC, or CA

Volts x x x x x x xa x

V1_MAG Voltage, positive-seq. mag. Volts x x x x x x x x x

V1_ANG Voltage, positive-seq., ang. degrees x x x x x x x x

V2_MAG Voltage, neg.-seq., Y-terminals, mag. Volts x x x x x x x x x

V2_ANG Voltage, neg.-seq., ang. degrees x x x x x x x x

3V0_MAG (9) Voltage, 3-phase zero-seq. mag. Volts x x x x x x x x x

3V0_ANG (9) Voltage, 3-phase zero-seq., ang. degrees x x x x x x x x

MWx (9) Real power mag., x-phase where

x = A, B, or C

Watts x x x x x x x x

MW3 Real power magnitude, 3-phase Watts x x x x x x x x

MWx_AVG (9) Real power RMS mag., x-phase where

x = A, B, or C

Watts x x x x x x x x

MW3_AVG Real power RMS magnitude, 3-phase Watts x x x x x x x x

MVRx(9) Reactive power mag., x-phase where

x = A, B, or C

VAR x x x x x x x

H.3


Analog Quantities

MVRxI_LD (9) Reactive power mag., x-phase in leading where x = A, B, or C

VAR x x

MVRxI_LG (9) Reactive power mag., x-phase in lagging where x = A, B, or C

VAR x x

MVRxO_LD (9) Reactive power mag., x-phase out leading where x = A, B, or C

VAR x x

MVRxO_LG (9) Reactive power mag., x-phase out lagging where x = A, B, or C

VAR x x

MVRx_AVG (9) Reactive power RMS mag., x-phase where x = A, B, or C

VAR x x x x x x x x

MVR3 Reactive power mag., 3-phase VAR x x x x x x x

MVR3I_LD Reactive power mag., 3-phase in leading

VAR x x x

MVR3I_LG Reactive power mag., 3-phase in lagging

VAR x x x

MVR3O_LD Reactive power mag., 3-phase out leading

VAR x x x

MVR3O_LG Reactive power mag., 3-phase out lagging

VAR x x x

MVR3_AVG Reactive power RMS mag., 3-phase VAR x x x x x x x x

MVAx (9) Apparent power mag., x-phase where x = A, B, C, or 3

VA x x x x x x x

MVAx_U (9) Apparent power RMS mag., x-phase where x = A, B, C, or 3

VA x x x x x x x x

MVA3 Apparent power mag., 3-phase VA x x x x x x x

MVA3_U Apparent power RMS mag., 3-phase VA x x x x x x x x

PFx (9) Displacement power factor mag., x-phase where x = A, B, or C

per unit x x x x x x x x x

PF3 Displacement power factor mag., 3-phase

per unit x x x x x x x x x

LDPFx (9) Displacement power factor sign, x-phase where x = A, B, or C

0 or 1 x x x x

LDPF3 Displacement power factor sign, 3-phase

0 or 1 x x x

PFTx (9) True power factor mag., x-phase where x = A, B, or C

per unit x

PFT3 (9) True power factor mag., 3-phase per unit x

LDPFTx (9) True power factor lead (1) or lag, x-phase where x = A, B, or C

0 or 1 x

LDPFT3 (9) True power factor lead (1) or lag, 3-phase

0 or 1 x

FREQ Frequency Hz x x x x x x x x x

DEV_Vx % of Voltage nominalwhere x = (A, B, C for Form 9; AB, BC, CA for Form 5)

% x x x x

DEV_F % of Frequency nominal % x x x x



Usage

MET (Pri)

HMI (Pri)

LDP (Sec)

DP (Pri)

Logic (Sec)

DNP (Pri)

Modbus (Sec)

FM(Pri)

AO (Pri)

H.4


Analog Quantities

I_AVE Average Current, 3-phase Amps x x x x

V_AVE Average Voltage, 3-phase Volts x x x x

I_IMB Imbalance, Current % x x x x

V_IMB Imbalance, Voltage % x x x x

Ix_REb Real component of Ix where x = A, B, C, or N

Amps sec x x

Ix_IMb Imaginary component of Ix where x = A, B, C, or N

Amps sec x x

Vx_REb Real component of Vx where x = A, B, or C

Volts sec x x

Vx_IMb Imaginary component of Vx where x = A, B, or C

Volts sec x x

a Line-to-Line voltages are not available from Form 9 meters when using Modbus.b Real and imaginary currents are scaled in ADC counts (1489) for CL10/CL20 meters and (5079) for CL2 meters. Real and imaginary voltages are

scaled in ADC counts (145).

Table H.2 Demand Metering (Sheet 1 of 2)


Usage

MET (Pri)

PRED (Pri)

HMI (Pri)

LDP (Sec)

DP (Pri)

Logic (Sec)

DNP (Pri)

Modbus (Sec)

FM(Pri)

AO(Pri)

IxD Current, x-phase, mag. where x = A, B, or C

Amps x x x x x x x x x x

IND Current, neutral, mag. Amps x x x x x x x

IGD Current, neutral or residual (auto switching), mag.

Amps x x x

3I2D Current, 3-phase neg.-seq., mag.

Amps x x x

MVAxDI (9) Apparent power mag., x-phase IN where x = A, B, or C

VA x x x x x x x x x

MVA3DI Apparent power mag., 3-phase IN


MVAxDO (9) Apparent power mag., x-phase OUT where x = A, B, or C


MVA3DO Apparent power mag., 3-phase OUT


MWxDI (9) Real power mag., x-phase IN where x = A, B, or C

Watts x x x x x x x x x x

MW3DI Real power mag., 3-phase IN


MWxDO (9) Real power mag., x-phase OUT where x = A, B, or C


MW3DO Real power mag., 3-phase OUT




Usage

MET (Pri)

HMI (Pri)

LDP (Sec)

DP (Pri)

Logic (Sec)

DNP (Pri)

Modbus (Sec)

FM(Pri)

AO (Pri)

H.5


Analog Quantities

MVRxDI_LG (9) Reactive power mag., x-phase IN lagging where x = A, B, or C

VAR x x x x x x x

MVR3DI_LG Reactive power mag., 3-phase IN lagging

VAR x x x x x x x

MVRxDI_LD (9) Reactive power mag., x-phase IN leading where x = A, B, or C

VAR x x x x x x x

MVR3DI_LD Reactive power mag., 3-phase IN leading

VAR x x x x x x x

MVRxDI (9) Reactive power mag., x-phase IN where x = A, B, or C

VAR x x x x x x x x x x

MVR3DI Reactive power mag., 3-phase IN


MVRxDO_LG (9) Reactive power mag., x-phase OUT lagging where x = A, B, or C

VAR x x x x x x x

MVR3DO_LG Reactive power mag., 3-phase OUT lagging

VAR x x x x x x x

MVRxDO_LD (9) Reactive power mag., x-phase OUT leading where x = A, B, or C

VAR x x x x x x x

MVR3DO_LD Reactive power mag., 3-phase OUT leading

VAR x x x x x x x

MVRxDO (9) Reactive power mag., x-phase OUT where x = A, B, or C


MVR3DO Reactive power mag., 3-phase OUT


Table H.3 Peak Demand Metering (Sheet 1 of 3)


Usage

MET (Pri)

HMI (Pri)

LDP (Sec)

DP (Pri)

Logic (Sec)

DNP(Pri)

Modbus (Sec)

FM (Pri)

AO (Pri)

IxPK Current, x-phase, mag. where x = A, B, C, N, or G

Amps x x x x x x x x x

3I2PK Current, 3-Phase neg.-seq., mag. Amps x x x x x x x x x

MVAxPI (9) Apparent power mag., x-phase IN where x = A, B, or C

VA x x x x x x x x

MVA3PI Apparent power mag., 3-phase IN VA x x x x x x x x

MVAxPO (9) Apparent power mag., x-phase OUT where x = A, B, or C

VA x x x x x x x x

MVA3PO Apparent power mag., 3-phase OUT

VA x x x x x x x x

MWxPI(9) Real power mag., x-phase IN where x = A, B, or C

Watts x x x x x x x x x

Table H.2 Demand Metering (Sheet 2 of 2)


Usage

MET (Pri)

PRED (Pri)

HMI (Pri)

LDP (Sec)

DP (Pri)

Logic (Sec)

DNP (Pri)

Modbus (Sec)

FM(Pri)

AO(Pri)

H.6


Analog Quantities

MW3PI Real power mag., 3-phase IN Watts x x x x x x x x x

MWxPO (9) Real power mag., x-phase OUT where x = A, B, or C

Watts x x x x x x x x x

MW3PO Real power mag., 3-phase OUT Watts x x x x x x x x x

MVRxPI_LG (9) Reactive power mag., x-phase IN Lagging where x = A, B, or C

VAR x x x x

MVR3PI_LG Reactive power mag., 3-phase IN Lagging

VAR x x x x

MVRxPI_LD (9) Reactive power mag., x-phase IN Leading where x = A, B, or C

VAR x x x x

MVR3PI_LD Reactive power mag., 3-phase IN Leading

VAR x x x x

MVRxPI (9) Reactive power mag., x-phase IN where x = A, B, or C

VAR x x x x x x x x x

MVR3PI Reactive power mag., 3-phase IN VAR x x x x x x x x x

MVRxPO_LG (9) Reactive power mag., x-phase OUT Lagging where x = A, B, or C

VAR x x x x x x

MVR3PO_LG Reactive power mag., 3-phase OUT Lagging

VAR x x x x x x

MVRxPO_LD (9) Reactive power mag., x-phase OUT Leading where x = A, B, or C

VAR x x x x x x

MVR3PO_LD Reactive power mag., 3-phase OUT Leading

VAR x x x x x x

MVRxPO (9) Reactive power mag., x-phase OUT where x = A, B, or C


MVR3PO Reactive power mag., 3-phase OUT


IxPKT Date/time of peak current, x-phase where x = A, B, C, or N

x x

MVAxPIT (9) Date/time of peak apparent power, x-phase, IN where x = A, B, or C

x x

MVA3PIT Date/time of peak apparent power, 3-phase, IN

x x

MVAxPOT (9) Date/time of peak apparent power, x-phase, OUT where x = A, B, or C

x x

MVA3POT Date/time of peak apparent power, 3-phase, OUT

x x

MWxPIT (9) Date/time of peak real power, x-phase, IN where x = A, B, or C

x x

MW3PIT Date/time of peak real power, 3-phase, IN

x x

MWxPOT (9) Date/time of peak real power, x-phase, OUT where x = A, B, or C

x x



Usage

MET (Pri)

HMI (Pri)

LDP (Sec)

DP (Pri)

Logic (Sec)

DNP(Pri)

Modbus (Sec)

FM (Pri)

AO (Pri)

H.7


Analog Quantities

MW3POT Date/time of peak real power, 3-phase, OUT

x x

MVRxPITLG (9) Date/time of peak reactive power, x-phase IN Lagging where x = A, B, or C

x

MVR3PITLG Date/time of peak reactive power, 3-phase IN Lagging

x

MVRxPITLD (9) Date/time of peak reactive power, x-phase IN Leading where x = A, B, or C

x

MVR3PITLD Date/time of peak reactive power, 3-phase IN Leading

x

MVRxPIT (9) Date/time of peak reactive power, x-phase IN Net where x = A, B, or C

x x

MVR3PIT Date/time of peak reactive power, 3-phase IN Net

x x

MVRxPOTLG (9) Date/time of peak reactive power, x-phase OUT Lagging where x = A, B, or C

x

MVR3POTLG Date/time of peak reactive power, 3-phase OUT Lagging

x

MVRxPOTLD (9) Date/time of peak reactive power, x-phase OUT Leading where x = A, B, or C

x

MVR3POTLD Date/time of peak reactive power, 3-phase OUT Leading

x

MVRxPOT (9) Date/time of peak reactive power, x-phase OUT Net where x = A, B, or C

x x

MVR3POT Date/time of peak reactive power, 3-phase OUT Net

x x

Table H.4 Energy Metering (Sheet 1 of 2)


Usage

MET (Pri)

HMI (Pri)

LDP (Sec)

DP (Pri)

Logica (Sec)

DNP (Pri)

Modbus (Sec)

FM (Pri)

AO (Pri)

MWHxI (9) Real energy, x-phase IN where x = A, B, or C

Watt-hours x x x x x x x x

MWH3I Real energy, 3-phase IN Watt-hours x x x x x x x x

MWHxO (9) Real energy, x-phase OUT where x = A, B, or C


MWH3O Real energy, 3-phase OUT Watt-hours x x x x x x x x

MWHx_NET (9) Real energy, x-phase NET where x = A, B, or C


MWH3_NET Real energy, 3-phase NET Watt-hours x x x x x x x x

MVAHxI (9) Apparent energy, x-phase IN where x = A, B, or C

VA-hours x x x x x x x x



Usage

MET (Pri)

HMI (Pri)

LDP (Sec)

DP (Pri)

Logic (Sec)

DNP(Pri)

Modbus (Sec)

FM (Pri)

AO (Pri)

H.8


Analog Quantities

MVAH3I Apparent energy, 3-phase IN VA-hours x x x x x x x

MVAHxO (9) Apparent energy, x-phase OUT where x = A, B, or C

VA-hours x x x x x x x

MVAH3O Apparent energy, 3-phase OUT VA-hours x x x x x x x

MVRHxI_LG (9) Reactive energy, x-phase IN LAG where x = A, B, or C

VAR-hours x x x x x x x x

MVRH3I_LG Reactive energy, 3-phase IN LAG VAR-hours x x x x x x x x

MVRHxI_LD (9) Reactive energy, x-phase IN LEAD where x = A, B, or C


MVRH3I_LD Reactive energy, 3-phase IN LEAD


MVRHxI (9) Reactive energy, x-phase IN where x = A, B, or C


MVRH3I Reactive energy, 3-phase IN VAR-hours x x x x x x x x

MVRHxO_LG (9) Reactive energy, x-phase OUT LAG where x = A, B, or C


MVRH3O_LG Reactive energy, 3-phase OUT LAG


MVRHxO_LD (9) Reactive energy, x-phase OUT LEAD where x = A, B, or C


MVRH3O_LD Reactive energy, 3-phase OUT LEAD


MVRHxO (9) Reactive energy, x-phase OUT where x = A, B, or C


MVRH3O Reactive energy, 3-phase OUT VAR-hours x x x x x x x x

MVRH3_NET Reactive energy, 3-phase NET VAR-hours x

VHxI (9) Vh, x-phase where x = A, B, or C Volt-hours x x x x x x x

VH3I Vh, 3-phase Volt-hours x x x x x x x

VHxI (5) Vh, x-phase where x = AB, BC, or CA

Volt-hours x x x x x x x

IHx Ih, x-phase, where x = A, B, or C Amp-hours x x x x x x x x

IH3 Ih, 3-phase Amp-hours x x x x x x x x

IHN Ih, Neutral Amp-hours x x x x x x x x

a Quantities used in SELOGIC control equations are secondary values. Energy values are in kilo units (e.g., SV01 := MWH3I > 1.8 – SV01 is true when 3-phase Watt-hours IN exceeds 1.8 kWh secondary).

Table H.5 Monthly Frozen/Consumed Energy Values (Sheet 1 of 2)


Usage

MET (Pri)

HMI (Pri)

LDP (Sec)

DP (Pri)

Logic (Sec)

DNP (Pri)

Modbus (Sec)

FMAO

(Pri)

FMWH3I Real energy, 3-phase IN at start of present month

Watt-hours x x

FMWH3I_1M Real energy, 3-phase IN at start of previous month

Watt-hours x x

Table H.4 Energy Metering (Sheet 2 of 2)


Usage

MET (Pri)

HMI (Pri)

LDP (Sec)

DP (Pri)

Logica (Sec)

DNP (Pri)

Modbus (Sec)

FM (Pri)

AO (Pri)

H.9


Analog Quantities

FMWH3I_2M Real Energy, 3-phase IN at start of two months previous

Watt-hours x x

FMWH3O Real Energy, 3-phase OUT at start of present month

Watt-hours x x

FMWH3O_1M Real Energy, 3-phase OUT at start of previous month

Watt-hours x x

FMWH3O_2M Real Energy, 3-phase OUT at start of two months previous

Watt-hours x x

CMWH3I Consumed Real Energy, 3-phase IN for present month

Watt-hours x x

CMWH3I_1M Consumed Real Energy, 3-phase IN for previous month

Watt-hours x x

CMWH3I_2M Consumed Real Energy, 3-phase IN for two months previous

Watt-hours x x

CMWH3O Consumed Real Energy, 3-phase OUT for present month

Watt-hours x x

CMWH3O_1M Consumed Real Energy, 3-phase OUT for previous month

Watt-hours x x

CMWH3O_2M Consumed Real Energy, 3-phase OUT for two months previous

Watt-hours x x

Table H.5 Monthly Frozen/Consumed Energy Values (Sheet 2 of 2)


Usage

MET (Pri)

HMI (Pri)

LDP (Sec)

DP (Pri)

Logic (Sec)

DNP (Pri)

Modbus (Sec)

FMAO

(Pri)

Table H.6 DST Change Frozen/Consumed Energy Values


Usage

MET (Pri)

HMI (Pri)

LDP (Sec)

DP (Pri)

Logic (Sec)

DNP (Pri)

Modbus (Sec)

FMAO

(Pri)

FD_MWH3I Real Energy, 3-phase IN at DST change

Watt-hours x

FD_MVRH3I Reactive Energy, 3-phase IN at DST change

VAR-hours x

CD_MWH3I Consumed Real Energy, 3-phase IN at DST change

Watt-hours x

Table H.7 TOU Season Change Frozen/Consumed Energy Values


Usage

MET (Pri)

HMI (Pri)

LDP (Sec)

DP (Pri)

Logic (Sec)

DNP (Pri)

Modbus (Sec)

FMAO

(Pri)

FS_MWH3I Real Energy, 3-phase IN at TOU change

Watt-hours x

FS_MVRH3I Reactive Energy, 3-phase IN at TOU change

VAR-hours x

CS_MWH3I Consumed Real Energy, 3-phase IN at TOU change

Watt-hours x

H.10


Analog Quantities

Table H.8 Maximum/Minimum Metering


Usage

MET (Pri)

HMI (Pri)

LDP (Sec)

DP (Pri)

Logic (Sec)

DNP (Pri)

Modbus (Sec)

FMAO

(Pri)

IxMX Current, x-phase, max mag. where x = A, B, C, or N

Amps x x x x x x x

IxMN Current, x-phase, min mag. where x = A, B, C, or N

Amps x x x x x x x

VxMX (9) Voltage, x-phase-to-neutral, max mag. where x = A, B, or C

Volts x x x x x x x

VxMX (5) Voltage, x-phase-to-neutral, max mag. where x = AB, BC, or CA

Volts x x x x x x x

VxMN (9) Voltage, x-phase-to-neutral, min mag. where x = A, B, or C

Volts x x x x x x x

VxMN (5) Voltage, x-phase-to-neutral, min mag. where x = AB, BC, or CA

Volts x x x x x x x

MW3MX Real power mag., 3-phase, max Watts x x x x x x x

MVR3MX Reactive power mag., 3-phase, max VAR x x x x x x x

MW3MN Real power mag., 3-phase, min Watts x x x x x x x

MVR3MN Reactive power mag., 3-phase, min VAR x x x x x x x

IxCFMX Current, x-phase, max crest factor mag. where x = A, B, C, or N

Amps x x x x x x x

VxCFMX (9) Voltage, x-phase-to-neutral max crest factor mag. where x = A, B, or C

Volts x x x x x x x

VxCFMX (5) Voltage, phase-to-phase x max crest factor mag. where x = AB, BC, or CA

Volts x x x x x x x

IxCFMN Current, x-phase, min crest factor mag. where x = A, B, C, or N

Amps x x x x x x x

VxCFMN (9) Voltage, x-phase-to-neutral min crest factor mag. where x = A, B, or C

Volts x x x x x x x

VxCFMN (5) Voltage, phase-to-phase x min crest factor mag. where x = AB, BC, or CA

Volts x x x x x x x

Table H.9 Harmonics Meteringa (Sheet 1 of 2)

Name Description UnitsUsage

MET HMI LDP DP Logic DNP Modbus FM AO

THDIx THD, Current, x-phase, mag. where x = A, B, C, or N

% x x x x x x x x

THDVx (9) THD Voltage, x-phase-to-neutral mag. where x = A, B, or C

% x x x x x x x x

THDVx (5) THD Voltage, x-phase mag. where x = AB, BC, or CA

% x x x x x x x x

THDGIx THDG Current, x-phase mag. where x = A, B, C, or N)

% x x x x x x x x

THDGVx (9) THDG Voltage, x-phase-to-neutral mag. where x = A, B, or C)

% x x x x x x x x

THDGVx (5) THDG Voltage, x-phase mag. where x = AB, BC, or CA)

% x x x x x x x x

KF_x K factor, x-phase mag. where x = A, B, or C

x x x x x x x x

H.11


Analog Quantities

DP_x (9) Distortion power, x-phase where x = A, B, or C

% x x x x x x x x

DP_3 Distortion power, 3-phase % x x x x x x x x

HRMn_xx nth harmonic percent for fundamental, current, or voltage where n = 2 . . . 15 (07340) or n = 2 . . . 50 (0734P), xx = (IA, IB, IC, IN) or (Va, Vb, Vc for Form 9; VAB, VBC, VCA for Form 5)

% xb xb xb xb xc (2nd–15th)

xc xb

HRMn_xxM nth harmonic current or voltage mag. where n = 2 . . . 15 (07340) or n = 2 . . . 50 (0734P), xx = (IA, IB, IC, IN) or (VA, VB, VC)

Amps or Volts,

secondary

xb xb xb xc xc x

HRMn_xx_A nth harmonic current or voltage ang. where n = 2 . . . 15 (07340) or n = 2 . . . 50 (0734P), xx = (IA, IB, IC, IN) or (VA, VB, VC)

Degrees x x x x x x

HRMn_xP nth harmonic power where n = 2 . . . 15 (07340) or n = 2 . . . 50 (0734P), x = (A, B, C)

Watts, secondary

x x x x x x

HRMn_3P nth harmonic power where n = 2 . . . 15 (07340) or n = 2 . . . 50 (0734P)

Watts, secondary

x x x x x x

IHRMz_xx Harmonic and interharmonic percentage, current or voltage. where z = frequency, xx = (IA, IB, IC, IN) or (Va, Vb, Vc for Form 9; VAB, VBC, VCA for Form 5)

% xd

IHRMz_xx Harmonic and interharmonic magnitude, current or voltage. where z = frequency, xx = (IA, IB, IC, IN) or (VA, VB, VC)

Amps or Volts,

secondary

xd

a For a Form 5 meter, the values for IB, VB, VBC, and B (power) are always zero (0).b Quantities will include interharmonics when the Included Interharmonics setting (INCIHQ) is set to Y (Yes).c Quantities will include interharmonics when the respective Modbus or DNP Include Interharmonics setting is set to one (1).d Quantities represent the frequency spectrum from just below the fundamental to slightly past the 50th harmonic.

Table H.10 Flicker Metering



PST_Vx Short-Term Flicker Evaluation Results where x = (A, B, C for Form 9; AB, BC, CA for Form 5). Updated every 10 min.

x x x x x x x

PLT_Vx Long-Term Flicker Evaluation Results where x = (A, B, C for Form 9; AB, BC, CA for Form 5). Updated every two hours.

x x x x x x x

SEC_PST Seconds until next valid PST results Seconds x x x x x

SEC_PLT Seconds until next valid PLT results Seconds x x x x x

Table H.9 Harmonics Meteringa (Sheet 2 of 2)



H.12


Analog Quantities

Table H.11 Diagnostics


STA HMI LDP DP Logic DNP Modbusa

a For Modbus, an OK, WARN, or FAIL enumerated value is returned instead of the actual voltage or temperature.

CASC FM AO

+5V_PS Five volt power supply Vdc x x x x x

+3.3V_PS Positive 3.3 V regulator output Vdc x x x x x



–1.25_PS Negative 1.25 V regulator output Vdc x x x x x

–5V_PS Negative 5 V regulator output Vdc x x x x x

BATT Real Time clock battery voltage Vdc x x x x x

TEMP Internal Temp Deg C x x x x x

Table H.12 Date/Time


DAT HMI LDP DP Logic DNP Modbus CASC FM AO

DATE Present date x x x x x

TIME Present time x x x x x

DATE_TIME Present date and time x

YEAR Year number (0000–9999) x x

DAYY Day of Year number (1–366) x x

WEEK Week number (1–52) x x

DAYW Day of Week number (1–7) x x

MINSM Minutes since Midnight x

Table H.13 SELOGIC Counters


COU HMI LDP DP Logic DNP Modbus CASC FM AO

SCnn SELOGIC counter nn present value x x x x x x

Table H.14 SELOGIC Math Variables


MAT HMI LDP DP Logic DNP Modbus CASC FM AO

MVnn SELOGIC math variable nn present value

x x x x x x

Table H.15 DNP Remote Analog Output Objects



RAxx DNP Analog Outputs. xx = 00–31 x x x

H.13


Analog Quantities

Time-of-Use (TOU) The following quantities require a prefix and a qualifier for either the TOU rate or ranking of peak values. Follow Table H.19 to determine which prefix or qualifier to apply when using an analog quantity.

Examples:

➤ Present Season 3-Phase Apparent Energy for rate C: PRES_MVAH_C

➤ Self-Read 3 Previous Season Peak Demand for rate B: S3PREV_MW_B_PD

Table H.16 Analog Control Values



ACVxx Analog Control Values. xx = 01–32 x x x

Table H.17 Analog Inputs


MET HMI LDP DP Logic DNP Modbus CASC FM AO

AI301 Analog Input 301 x x x x x x x x

Table H.18 Transformer Ratio Settings



PTR PT Ratio x x x x

CTR Phase CT Ration x x x x

CTRN Neutral CT Ratio x x x x

Table H.19 Prefix and Qualifier Descriptions

Prefix or Qualifier

PlaceholderValid Prefix or Qualifier Description

Z PRES, PREV, SnPRES, or SnPREV. Select between present season or previous season. Substitute n with 1, 2, or 3, to indicate which self read to use.

x A, B, C, D, E, or F Substitute x with the TOU rate, A–F, to use.

n 1, 2, 3, 4, or 5 Substitute n with the ranking of peak value, 1–5, to use.

Table H.20 Time-of-Use (Sheet 1 of 4)


Usage

DAT HMI LDP DP Logic DNP ModbusFM

(Pri)AO

Z_MWH_x_TOT 3-phase real energy total for rate x

x x x

Z_MVAH_x_TOT 3-phase apparent energy total for rate x

x x x

Z_MVARH_x_TOT 3-phase total reactive energy for rate x

x x x

Z_MWH_x_REC 3-phase real energy received for rate x

x x x

Z_MVAH_x_REC 3-phase apparent energy received for rate x

x x x

H.14


Analog Quantities

Z_MVARH_x_REC 3-phase reactive energy received for rate x

x x x

Z_MWH_TOTAL_REC Total 3-phase reactive received energy

x x x

Z_MVARH_TOTAL_REC Total 3-phase reactive received energy

x x x

Z_MWH_AT_RESET Total 3-phase real energy at the time of the last demand reset

x x x

Z_MWH_SINCE_RESET Total 3-phase real energy since the time of the last demand reset

x x x

Z_MVAH_AT_RESET Total 3-phase apparent energy at the time of the last demand reset

x x x

Z_MVAH_SINCE_RESET Total 3-phase apparent energy since the time of the last demand reset

x x x

Z_MVARH _AT_RESET Total 3-phase reactive energy at the time of the last demand reset

x x x

Z_MVARH_SINCE_RESET Total 3-phase reactive energy since the time of the last demand reset

x x x

Z_MW_x_PD Value, time, and date of 3-phase peak real power for rate x

x x x

Z_MVA_x_PD Value, time, and date of 3-phase peak apparent power for rate x

x x x

Z_MVAR_x_PD Value, time, and date of 3-phase peak reactive power for rate x

x x x

Z_MW_x_REC_PD Value, time, and date of 3-phase received peak real power for rate x

x x x

Z_MVA_x_REC_PD Value, time, and date of 3-phase received peak apparent power for rate x

x x x

Z_MVAR_x_REC_PD Value, time, and date of 3-phase received peak reactive power for rate x

x x x

Z_PF_AT_MW_1_PD Power factor at the highest peak real power for rate x

x x x

Z_PF_AT_MVA_1_PD Power factor at the highest peak apparent power for rate x

x x x



Usage


(Pri)AO

H.15


Analog Quantities

Z_PF_AT_MVAR_1_PD Power factor at the highest peak reactive power for rate x

x x x

Z_PF_AT_MW_1_REC_PD Power factor at the highest received peak real power for rate x

x x x

Z_PF_AT_MVA_1_REC_PD Power factor at the highest received peak apparent power for rate x

x x x

Z_PF_AT_MVAR_1_REC_PD Power factor at the received peak reactive power for rate x

x x x

Z_MW_n_PD Value, time, and date of 3-phase peak real power number n

x x x

Z_MVA_n_PD Value, time, and date of 3-phase peak apparent power number n

x x x

Z_MVAR_n_PD Value, time, and date of 3-phase peak reactive power number n

x x x

Z_MW_n_REC_PD Value, time, and date of 3-phase received peak real power number n

x x x

Z_MVA_n_REC_PD Value, time, and date of 3-phase received peak apparent power num-ber n

x x x

Z_MVAR_n_REC_PD Value, time, and date of 3-phase received peak reactive power num-ber n

x x x

Z_PF_AT_MW_n_PD Power factor at the num-ber n peak real power

x x x

Z_PF_AT_MVA_n_PD Power factor at the num-ber n peak apparent power

x x x

Z_PF_AT_MVAR_n_PD Power factor at the number n peak reactive power

x x x

Z_PF_AT_MW_n_REC_PD Power factor at the num-ber n received peak real power

x x x

Z_PF_AT_MVA_n_REC_PD Power factor at the num-ber n received peak appar-ent power

x x x

Z_PF_AT_MVAR_n_REC_PD Power factor at the num-ber n received peak reac-tive power

x x x

Z_MW_x_CD 3-phase real power cumu-lative demand for rate x

x x x



Usage


(Pri)AO

H.16


Analog Quantities

Z_MVA_x_CD 3-phase apparent power cumulative demand for rate x

x x x

Z_MVAR_x_CD 3-phase reactive power cumulative demand for rate x

x x x

Z_MW_CD 3-phase real power cumu-lative demand

x x x

Z_MVA_CD 3-phase apparent power cumulative demand

x x x

Z_MVAR_CD 3-phase reactive power cumulative demand

x x x

Z_MW_MAX_AT_RESET Max real power as of the last demand reset

x x x

Z_MVAR_MAX_AT_RESET Max reactive power as of the last demand reset

x x x

Z_MW_AT_MIN_PF_AT_RESET

Real power at the time the min PF occurred as of the last demand reset

x x x

Z_MW_AT_MIN_PF_SINCE_RESET

Real power at the time the min PF occurred since the last demand reset

x x x

Z_PF_MIN_AT_RESET Min power factor as of the last demand reset

x x x

Z_PF_MIN_SINCE_RESET Min power factor since the last demand reset

x x x

Z_PF_AVG_AT_RESET Average power factor as of the last demand reset

x x x

Z_PF_AVG_SINCE_RESET Average power factor since the last demand reset

x x x

Z_NUM_DEMAND_RESET Number of demand resets performed

x x x

Z_TIME_OF_LAST_DEMAND_RESET

Time and date of the last demand reset

x x x



Usage


(Pri)AO


Glossary

a Output A meter control output that closes when the output meter asserts.

b Output A meter control output that opens when the output meter asserts.

c Contact A breaker auxiliary contact that can be set to serve either as an a contact or as a b contact.

A Abbreviation for amps or amperes; unit of electrical current flow.

Acceptance Testing Testing that confirms that the meter meets published critical performance specifications and requirements of the intended application. Such testing involves accuracy testing and logic functions when qualifying a meter model for use on the utility system.

Access Level A meter command level with a specified set of meter information and commands. Except for Access Level 0, you must have the correct password to enter an access level.

Access Level 0 The least secure and most limited access level. No password protects this level. From this level, you must enter a password to go to a higher level.

Access Level 1 A meter command level you use to monitor (view) meter information. The default access level for the meter front panel.

Access Level E A meter command level you use for Access Level 1 functions and resetting of peak demand, max/mins, crest factors, and load profile. This access level is for the meter reader.

Access Level 2 The most secure access level where you have total meter functionality and control of all settings types.

ACSELERATORQuickSet®

SEL-5030 Software

A Windows®-based program that simplifies settings and provides analysis support.

Analog Quantities Variables represented by such fluctuating measurable quantities as frequency, current, and voltage.

AND Operator Logical AND. An operator in Boolean SELOGIC® control equations that requires fulfillment of conditions on both sides of the operator before the equation is true.

Anti-Aliasing Filter A low pass filter that blocks frequencies too high for the given sampling rate to accurately reproduce.

Apparent Power (S) Complex power expressed in units of volt-amps (VA). Accounts for both real (P) and reactive (Q) power dissipated in a circuit: S = P + jQ. This is power at the fundamental frequency only; no harmonics are included in this quantity.

ASCII Abbreviation for American Standard Code for Information Interchange. Defines a standard set of text characters. The SEL-734 uses ASCII text characters to communicate using front-panel and rear-panel EIA-232 serial ports on the meter and through virtual serial ports.

GL.2


GlossaryASCII Terminal—Comparison

ASCII Terminal A terminal without built-in logic or local processing capability that can only send and receive information.

Assert To activate. To fulfill the logic or electrical requirements needed to operate a device. To set a logic condition to the true state (logical 1) of that condition. To apply a closed contact to an SEL-734 input. To close a normally open output contact. To open a normally closed output contact.

AT Modem Command SetDialing String Standard

The command language standard that Hayes Microcomputer Products, Inc. developed to control auto-dial modems from an ASCII terminal (usually EIA-232 connected) or a PC (personal computer) containing software allowing emulation of such a terminal.

Automatic Messages Messages including status failure and status warning messages that the meter generates at the serial ports and displays automatically on the front-panel LCD.

Bandpass Filter A filter that passes frequencies within a certain range and blocks all frequencies outside this range.

Bit Label The identifier for a particular bit.

Bit Value Logical 0 or logical 1.

Blondel’s Theorem This theorem states that in a system of N conductors, N-1 meter elements, properly connected, will measure the power or energy taken. The connection must be such that all voltage coils have a common tie to the conductor in which there is no current coil.

Boolean Logic Statements Statements consisting of variables that behave according to Boolean logic operators such as AND, NOT, and OR.

Checksum A method for checking the accuracy of data transmission involving summation of a group of digits and comparison of this sum to a previously calculated value.

CID Checksum identification of the firmware.

Class Designation The maximum of the watt-hour meter load range in amperes. This value is indicated on the faceplate after the abbreviation CL. Typical class designations for transformer-rated meters are CL 10 or CL 20. A typical class designation for a residential type meter is CL 200.

Cold Start Beginning a system from power up without carryover of previous system activities.

Commissioning Testing Testing that serves to validate all system ac and dc connections and confirm that the meter, auxiliary equipment, and SCADA interface all function as intended with your settings. Perform such testing when installing a new metering system.

Common Inputs Meter control inputs that share a common terminal.

Communications Protocol A language for communication between devices.

Comparison Boolean SELOGIC control equation operation that compares two numerical values. Compares floating-point values such as currents, total counts, and other measured and calculated quantities.

GL.3


GlossaryConditioning Timers—Dial

Conditioning Timers Timers for conditioning Boolean values. Conditioning timers either stretch incoming pulses or allow you to require that an input take a state for a certain period before reacting to the new state.

Contact Input See Control input.

Contact Output See Control output.

Control Input Meter inputs for monitoring the state of external circuits. Connect auxiliary meter and circuit breaker contacts to the control inputs.

Control Output Meter outputs that affect the state of other equipment. Connect control outputs and SCADA systems.

Counter Variable or device such as a register or storage location that either records or represents the number of times an event occurs.

CT Current transformer.

CTR Current transformer ratio.

Data Bit A single unit of information that can assume a value of either logical 0 or logical 1 and can convey control, address, information, or frame check sequence data.

Data Label The identifier for a particular data item.

Data Objects Individual pieces of UCA data created from instances of common class components or data items that are instances of standard data types.

DCE Devices Data communication equipment devices (modems).

Deadband The range of variation an analog quantity can traverse before causing a response.

Deassert To deactivate. To remove the logic or electrical requirements needed to operate a device. To clear a logic condition to its false state (logical 0). To open the circuit or open the contacts across an SEL-734 input. To open a normally open output contact. To close a normally closed output contact.

Debounce Time The time that masks the period when meter contacts continue to move after closing; debounce time covers this indeterminate state.

Default Data Map The default map of objects and indices that the SEL-734 uses in DNP protocol.

Delta A phase-to-phase series connection of circuit elements, particularly voltage transformers or loads.

Demand Meter A measuring function that calculates a rolling average, block, or thermal average, block, of instantaneous measurements over time.

Dial The clock-type hands on an electromechanical register. The “number of dials” on the meter must be known to the billing system in order to properly detect a rollover condition. Four- and five-dial registers are commonly used.

GL.4


GlossaryDial Multiplier—Event Report

Dial Multiplier The value displayed on the meter register multiplied by the dial multiplier to get kilowatt-hours. The dial multiplier is shown on the nameplate. For self-contained meters, a dial multiplier of one or ten is most common. For transformer-rated meters, the dial multiplier is determined at installation time depending on the transformer ratios. This multiplier applies to both the kilowatt-hour and demand (kW) readings.

DistortionPower Ratio (Dx)

Distortion power is calculated as the ratio of average power to fundamental power and is reported in a percentage. It is calculated on a per-phase or three-phase basis as follows:

where:

Dx is the distortion power ratio for the respective phase

Px_avg is the average power for the respective phase

Px is the fundamental power for the respective phase

DMSI Period The subinterval time of the demand meter time constant in demand metering.

DMTC Period The time of the demand meter time constant in demand metering.

DNP (DistributedNetwork Protocol)

Manufacturer-developed, hardware-independent communications protocol.

Dropout Time The time measured from the removal of an input signal until the output signal deasserts. You can set the time, in the case of a logic variable timer, or the dropout time can be a result of the characteristics of an element algorithm.

DTE Devices Data terminal equipment (computers, terminals, printers, meters, etc.).

Dumb Terminal See ASCII terminal.

EIA-232 Electrical definition for point-to-point serial data communications interfaces, based on the standard EIA/TIA-232. Formerly known as RS-232.

EIA-485 Electrical standard for multidrop serial data communications interfaces, based on the standard EIA/TIA-485. Formerly known as RS-485.

Element A combination of a voltage-sensing unit and a current-sensing unit that provides an output proportional to the quantities measured. For example, a Form 9 meter is a three-element meter. See also stator.

Energy Metering Energy metering provides a look at imported power, exported power, and net usage over time.

ESD(Electrostatic Discharge)

The sudden transfer of charge between objects at different potentials caused by direct contact or induced by an electrostatic field.

Ethernet A network physical and data link layer defined by IEEE 802.2 and IEEE 802.3.

Event History A quick look at recent meter activity that includes a standard report header; event number, date, time, type, and targets.

Event Report A text-based collection of data stored by the meter in response to a triggering condition, such as an ASCII TRI command. The data show meter

Dx Px_avgPx

------------------ 1–⎝ ⎠⎛ ⎞ 100=

GL.5


GlossaryEvent Summary—IED

measurements before and after the trigger, in addition to the states of elements each processing interval.

Event Summary A shortened version of stored event reports. An event summary includes items such as event date and time, event type.

The meter sends an event report summary (if auto messaging is enabled) to the meter serial port a few seconds after an event.

F_TRIG Falling-edge trigger. Boolean SELOGIC control equation operator that triggers an operation upon logic detection of a falling edge.

Fail-Safe Refers to an output that is open during normal meter operation and closed when meter power is removed or if the meter fails. Configure alarm outputs for fail-safe operation.

Falling Edge Transition from logical 1 to logical 0.

Fast Meter SEL binary serial port command used to collect metering data with SEL devices.

Fast Operate SEL binary serial port command used to perform control with SEL devices.

Firmware The nonvolatile program stored in the meter that defines meter operation.

Flash Memory A type of nonvolatile meter memory used for storing large blocks of nonvolatile data.

Flicker The visible, periodic change in light intensity of an incandescent bulb caused by the fluctuation of input voltage. IEC 61000-4-15 specifies the requirements for the measurement of flicker.

Function Code A code that defines how you manipulate an object in DNP3 protocol.

Fundamental Frequency The component of the measured electrical signal with a frequency equal to the normal electrical system frequency, usually 50 Hz or 60 Hz. Generally used to differentiate between the normal system frequency and any harmonic frequencies present.

Global Settings General settings including those for date format, phase rotation, control inputs, ASCII report scaling, and time and date management.

GPS Global Positioning System. Source of position and high-accuracy time information.

Group TotalHarmonic Distortion

The ratio of the sum of the power of all harmonic frequencies including interharmonics above the fundamental frequency to the power of the fundamental frequency. Usually expressed as a percentage, large numbers indicate increased distortion.

GUI Graphical user interface.

Hexadecimal Address A register address consisting of a numeral with an “h” suffix or a “0x” prefix.

HMI Human machine interface.

IA, IB, IC Measured A-phase, B-phase, and C-phase currents.

IED Intelligent electronic device.

GL.6


GlossaryIG—Maintenance Testing

IG Residual current, calculated from the sum of the phase currents. In normal, balanced operation, this current is very small or zero.

Input Conditioning The establishment of debounce time and assertion level.

Instantaneous Meter Type of meter data presented by the SEL-734 that includes the present values measured at the meter ac inputs. The word “Instantaneous” is used to differentiate these values from the measurements presented by the demand, energy, and other meter types.

IRIG-B A time code input that the meter can use to set the internal meter clock.

Jitter Time, amplitude, frequency, or phase-related abrupt, spurious variations in duration, magnitude, or frequency.

Ke or KYZ OutputConstant

A pulse constant for the KYZ outputs of a solid-state meter, programmable in unit-hours per pulse.

Kh or Watt-hour Constant The number of watt-hours represented by one revolution of the disk in electromechanical meters—also called the Disk Constant. For a solid-state meter, Kh is essentially meaningless since there is no disk. However, ANSI C12.10 requires that Kh be displayed on the faceplate.

Kt or Test Constant The number of watt-hours represented by one test pulse in a solid-state meter. The test pulse is usually provided by an IR LED or a contact output.

K-factor A measure of the effect of harmonic load currents used for derating equipment (transformers), as described in ANSI/IEEE C57.110. The larger the K-factor the greater the harmonic heating effects. A K-factor of 1.0 indicates a linear load (no harmonics). K-factor is the summation of the square of a particular harmonic current multiplied by the square of the harmonic number. K-factor transformers have additional thermal capacity, design features that minimize harmonic current losses, and oversized thermal connections.

KYZ Output A three-wire (Form C contact) output from a metering device to drive external control or recording equipment. Each pulse or transition represents a predetermined increment of energy or other quantity.

L/R Circuit inductive/resistive ratio.

Latch Bits Nonvolatile storage locations for binary information.

LED Light-emitting diode. Used as indicators on the meter front panel.

LMD SEL Distributed Port Switch protocol.

Logical 0 A false logic condition, dropped out element, or deasserted control input or control output.

Logical 1 A true logic condition, picked up element, or asserted control input or control output.

Low-Level Test Interface An interface that provides a means for interrupting the connection between the meter input transformers and the input processing module and allows inserting reduced-scale test quantities for meter testing.

Maintenance Testing Testing that confirms that the meter is measuring ac quantities accurately and verifies correct functioning of auxiliary equipment and scheme logic.

GL.7


GlossaryMath Operators—Nonvolatile Memory

Math Operators Operators that you use in the construction of math SELOGIC control equations to manipulate numerical values and provide a numerical base-10 result.

Maximum Dropout Time The maximum time interval following a change of input conditions between the deassertion of the input and the deassertion of the output.

Maximum/MinimumMeter

Type of meter data presented by the SEL-734 that includes a record of the maximum and minimum of each value, along with the date and time that each maximum and minimum occurred.

Meter Form The design of the measuring portion of the electric meter so that the meter can correctly measure the electric service supplied by the utility. There are many different forms because of the different types of electric service and the size of the service. Meter forms are defined in ANSI C12.10. Socket-based meters use an “S” suffix in the form number, e.g., “2S.” Bottom-connected meters, also known as “A-base” meters, use an “A” suffix, e.g., “9A.” The commonly used residential meter is the Form 2S, three-wire, self-contained. It is used on a 120/240 V service. The Form 9 meter is commonly used in substation metering. A Form 9 meter is a three-stator, transformer-rated, three-phase, four-wire wye.

Meter Word Bit A single meter element or logic result. A Meter Word bit can equal either logical 1 or logical 0. Logical 1 represents a true logic condition, picked up element, or asserted control input or control output. Logical 0 represents a false logic condition, dropped out element, or deasserted control input or control output. Use Meter Word bits in SELOGIC control equations.

MID Meter firmware identification string. Lists the meter model, firmware version and date code, and other information that uniquely identifies the firmware installed in a particular meter.

MIRRORED BITS®

CommunicationsPatented meter-to-meter communications technique that sends internal logic status, encoded in a digital message, from one meter to the other. Eliminates the need for some communications hardware.

MMS Manufacturing Messaging Specification, a data exchange protocol used by UCA.

Model Model of device (or component of a device) including the data, control access, and other features in UCA protocol.

Negation Operator A SELOGIC control equation math operator that changes the sign of the argument. The argument of the negation operation is multiplied by –1.

Negative-Sequence A configuration of three-phase currents and voltages. The currents and voltages have equal magnitude and a phase displacement of 120°, and have clockwise phase rotation with current and voltage maxima that occur differently from that for positive-sequence configuration. If positive-sequence maxima occur as ABC, negative-sequence maxima occur as ACB.

NEMA National Electrical Manufacturers’ Association.

NONVOL Nonvolatile memory where meter settings, event reports, SER records, and other nonvolatile data are stored.

Nonvolatile Memory Meter memory that persists over time to maintain the contained data even when the meter is de-energized.

GL.8


GlossaryNOT Operator—RAM

NOT Operator A logical operator that produces the inverse value.

Optical Port A communications interface on a metering product that allows the transfer of information while providing electrical isolation and metering security. The communications medium is typically infrared light transmitted and received through the meter cover.

OR Operator Logical OR. A Boolean SELOGIC control equation operator that compares two Boolean values and yields either a logical 1 if either compared Boolean value is logical 1 or a logical 0 if both compared Boolean values are logical 0.

Parentheses Operator Math operator. Use paired parentheses to control the execution of operations in a SELOGIC control equation.

PC Personal computer.

Peak Demand Metering Maximum demand and a time stamp for phase currents, negative-sequence and zero-sequence currents, and powers. The SEL-734 stores peak demand values and the date and time these occurred to nonvolatile storage overwriting the previously stored value if the new value is larger. Should the meter lose control power, the meter restores the peak demand information last stored.

Phase Rotation The sequence of voltage or current phasors in a multiphase electrical system. In an ABC phase rotation system, the B-phase voltage lags the A-phase voltage by 120°, and the C-phase voltage lags B-phase voltage by 120°. In an ACB phase rotation system, the C-phase voltage lags the A-phase voltage by 120°, and the B-phase voltage lags the C-phase voltage by 120°.

Pickup Time The time measured from the application of an input signal until the output signal asserts. You can set the time, as in the case of a logic variable timer, or the pickup time can be a result of the characteristics of an element algorithm.

Pinout The definition or assignment of each electrical connection at an interface. Typically refers to a cable, connector, or jumper.

Port Settings Communications port settings such as Data Bits, Speed, and Stop Bits.

Positive-Sequence A configuration of three-phase currents and voltages. The currents and voltages have equal magnitude and a phase displacement of 120°. With conventional rotation in the counter-clockwise direction, the positive-sequence current and voltage maxima occur in ABC order.

Power Factor The cosine of the angle by which phase current lags or leads phase voltage in an ac electrical circuit. Power factor equals 1.0 for power flowing to a pure resistive load.

PT Potential transformer. Also referred to as a voltage transformer or VT.

PTR Potential transformer ratio.

Qualifier Code Specifies type of range for DNP3 objects. With the help of qualifier codes, DNP master devices can compose the shortest, most concise messages.

R_TRIG Rising-edge trigger. Boolean SELOGIC control equation operator that triggers an operation upon logic detection of a rising edge.

RAM Random Access Memory. Volatile memory where the meter stores intermediate calculation results, Meter Word bits, and other data.

GL.9


GlossaryReal Power (P)—SELOGIC Expression Builder

Real Power (P) Power that produces actual work. The portion of apparent power that is real, not imaginary.

Real PowerAverage (PAVE)

Real power averaged over a one-second interval.

Real PowerThree Phase (P3P)

Three-phase real power measured in watts.

Reactive Power (Q) Reactive power measured in volt-amps reactive (VAR). The product of the voltage and current multiplied by the sine of the angle between the two.

Reactive PowerAverage (QAVE)

Reactive power (Q) average over a one-second interval. QAVE is forced to zero when the apparent power (S) is less than or equal to real power (P) • 0.001.

Reactive PowerThree Phase (Q3P)

Three-phase instantaneous reactive power measured in volt-amps reactive (VAR).

Register An electromechanical or electronic device which stores and displays metering quantities, e.g., kWh, kW demand. In solid-state meters, meter data quantities are often referred to as “registers.”

Remapping The process of selecting data from the default map and configuring new indices to form a smaller data set optimized to your application.

Remote Bit A Meter Word bit with a state that is controlled by serial port commands, including the CONTROL command, a binary Fast Operate command, DNP binary output operation, or a UCA control operation.

Report Settings Event report and Sequential Events Recorder settings.

Residual Current The sum of the measured phase currents. In normal, balanced operation, this current is very small or zero.

Rising Edge Transition from logical 0 to logical 1, or the beginning of an operation.

RMS Root-mean-square. This is the effective value of the current and voltage measured by the meter, accounting for the fundamental frequency and higher-order harmonics in the signal.

Rolling Demand A sliding time-window arithmetic average in demand metering.

RTU Remote Terminal Unit.

RXD Received data.

SCADA Supervisory control and data acquisition.

Self-Contained Meter A watt-hour meter that is connected directly to the supply voltage and is in series with the customer loads. Residential meters are almost always self-contained meters.

Self-Test A function that verifies the correct operation of a critical device subsystem and indicates detection of an out-of-tolerance condition. The SEL-734 has self-tests that validate the meter power supply, microprocessor, memory, and other critical systems.

SELOGICExpression Builder

A rules-based editor within the ACSELERATOR QuickSet software program for programming SELOGIC control equations.

GL.10


GlossarySELOGIC Math Variables—Total Harmonic Distortion (THD)

SELOGIC Math Variables Math calculation result storage locations.

SELOGICControl Equation

A meter setting that allows you to control a meter function (such as a control output) using a logical combination of meter element outputs and fixed logic outputs.

Sequencing Timers Timers designed for sequencing automated operations.

Sequential EventsRecorder

A meter function that stores a record of the date and time of each assertion and deassertion of every Meter Word bit in a list that you set in the meter. SER provides a useful way to determine the order and timing of events of a meter operation.

SER Sequential Events Recorder or the meter serial port command to request a report of the latest sequential events.

Settle/Settling Time Time required for an input signal to result in an unvarying output signal within a specified range.

Stator The unit that provides the driving torque in a watt-hour meter. It contains a voltage coil, one or more current coils, and the necessary steel to provide the required magnetic paths. Other names used for stator are element or driving element.

Status Failure A severe out-of-tolerance internal operating condition. The meter issues a status failure message and enters a disabled state.

Status Warning Out-of-tolerance internal operating conditions that do not compromise meter protection, yet are beyond expected limits. The meter issues a status warning message and continues to operate.

Strong Password A mix of valid password characters in a eight-character combination that does not spell common words in any portion of the password. Valid password characters are numbers, upper- and lower-case alphabetic characters, “.” (period), and “-” (hyphen).

Telnet An Internet protocol for exchanging terminal data that connects a computer to a network server and allows control of that server and communication with other servers on the network.

TerminalEmulation Software

Software that can be used to send and receive ASCII text messages and files via a computer serial port.

Thermal Demand Thermal demand is a continuous exponentially increasing or decreasing accumulation of metered quantities; used in demand metering.

ThermalWithstand Capability

The capability of equipment to withstand a predetermined temperature value for a specified time.

Time Delay on Pickup The time interval between initiation of a signal at one point and detection of the same signal at another point.

Time-of-Use Metering A metering method that records demand during selected periods of time so consumption during different time periods can be billed at different rates.

Total HarmonicDistortion (THD)

The ratio of the sum of the power of all harmonic frequencies above the fundamental frequency to the power of the fundamental frequency. Usually expressed as a percentage, large numbers indicate increased distortion.

GL.11


GlossaryTransformer Impedance—Z-Number

Transformer Impedance The resistive and reactive parameters of a transformer looking in to the transformer primary or secondary windings. Use industry accepted open-circuit and short-circuit tests to determine these transformer equivalent circuit parameters.

Transformer-Rated Meter A watt-hour meter that requires external instrument transformer(s) to isolate or step-down the current or voltage. Transformer-rated meters are usually located on high-current or high-voltage services. The meter reading on a transformer-rated meter is usually in secondary units. To convert to primary units, the reading must be multiplied by the dial multiplier, which should be shown on the meter faceplate.

TXD Transmitted data.

VA, VB, VC Measured A-phase-to-neutral, B-phase-to-neutral, and C-phase-to-neutral voltages.

VAB, VBC, VCA Measured or calculated phase-to-phase voltages.

Vector Power (U) Apparent power with the addition of distortion power representing the third dimension (k) in the power triangle. Measured in volt-amps (VA), U equals iP + jQ + kD, where kD is distortion power that is the result of harmonics and noise.

VirtualTerminal Connection

A mechanism that uses a virtual serial port to provide the equivalent functions of a dedicated serial port and a terminal.

Volatile Storage A storage device that cannot retain data following removal of meter power.

VT Voltage transformer. Also referred to as a potential transformer or PT.

Warm Start The reset of a running system without removing and restoring power.

Wye A phase-to-neutral connection of circuit elements, particularly voltage transformers or loads. To form a wye connection using transformers, connect the nonpolarity side of each of three voltage transformer secondaries in common (the neutral), and take phase to neutral voltages from each of the remaining three leads. When properly phased, these leads represent the A-phase-, B-phase-, and C-phase-to-neutral voltages. This connection is frequently called “four-wire wye,” alluding to the three phase leads plus the neutral lead.

Z-Number That portion of the meter MID string that identifies the proper ACSELERATOR QuickSet software meter driver version and HMI driver version when creating or editing meter settings files.



Index

Page numbers appearing in bold mark the location of the topic’s primary discussion.

AAcceptance Testing

See Testing

Access Commands 10.14

Access Levels 10.11See also Access Commands

communications ports 10.11, 10.12, 10.14

front panel 11.40, 1, E, 2 levels 10.11, 10.12, 10.13,

10.14

Accuracy

metering 1.9

Alarm

meter output 8.20

Analog Quantities H.1

ASCII Commands

See also Commands, ASCII

response header 10.13

ASCII Protocol 10.9See also Communications, protocols

Automatic Messages 10.11See also SEL Binary Protocols

front panel 11.2

BBattery, Clock 2.17

Block Demand Metering

See Demand Metering

BNA Command

See Commands, BNA

CCables, Serial 10.4

See also Communications

Calibration

See Meter, calibration

CAS Command

See Commands, CAS

CEVENT Command

See Event Report; Commands, CEV

CHISTORY Command

See Event History; Commands, CHI

Circuit Board

connections 2.16

COM Command

See Commands, COM

Commands

BNA 10.15CAS 10.15CEV 10.15

CHI 10.16

COM 10.15CON 10.29COU 10.16CST 10.16

CTR 10.16DAT 10.16, 10.27DNA 10.15DNP 10.16EVE 10.17EXI 10.15FIL DIR 10.17FIL READ 10.17FIL WRITE 10.29HIS 10.17ID 10.15IRI 10.28LDP 10.18, 10.28LOO 10.30MAT 10.18MET 10.22MET CF 10.19MET D 10.19MET D T 10.20MET E 10.20MET FL 10.21MET H 10.21MET H A 10.21MET H I 10.21MET H M 10.21MET H P 10.21MET H V 10.21MET L 10.21MET M 10.23MET PM 10.23PAS 10.31PUL 10.32QUI 10.24SER 10.24SET 10.33

SET E 10.33SHO 10.24SNS 10.15SSI 10.25STA 10.25

STA S 10.33STA SC 10.33STA SR 10.33TAR 10.26TEST MODE 10.33TIM 10.27, 10.29TOG 10.27TRI 10.27VER 10.33

Commissioning Testing

See Testing

Communications

ASCII Commands 10.13cables 2.15connections 1.6default, serial 10.4EIA-232

hardware flow control E.17pinout 10.5

Ethernet 10.4internal modem 10.1LMD

See Distributed Port Switch

Modbus RTU

See Modbus RTU

protocols 10.8

Communications Processor C.3

COMTRADE Command

See Commands, CTR

Configuration

serial number label 2.4, 2.5

Connections

communications ports 1.4, 2.7serial ports 2.7

Contact Inputs

See Optoisolated Inputs

Contact Outputs 8.19See also Connections

pulsing 10.32ratings 1.7

CONTROL Command

See Commands, CON

Control Outputs

See Contact Outputs

COU Command

See Commands, COU

IN.2 IndexD–L


Counter Variables 8.14application example 8.15

Crest Factor Metering 4.21update and storage 4.21viewing or resetting 4.21

CSTATUS Command

See Commands, CST

CT

See Current Transformer

Current Transformer

connections 2.11selecting 2.11

DDATE Command

See Commands, DAT

Demand Metering 4.7See also Commands, MET D;

MET D T; Meter; Predictive Demand

block demand metering 4.11peak demand times 10.20rolling demand characteristic 4.9settings 4.12thermal demand metering 4.9update and storage 4.14viewing or resetting 4.14

Demand Reset

See Time-of-Use

Design Templates 3.2

Diagrams

front panel 11.1, 11.3

Dimensions 2.1, 2.3

Display

See Front Panel, LCD

Display Points 8.22

Distortion Power

See Harmonic Metering

Distributed Network Protocol (DNP3) E.1

Distributed Port Switch B.1

DNA Command

See Commands, DNA

DNP Command

See Commands, DNP

EEarthing

See Grounding

EIA-232

See Communications

Energy Metering

See also Commands, MET E; Commands, SET E

cut-off point 4.15preloading 4.16update and storage 4.15viewing or resetting 4.15

Event 6.1See also Commands, EVE

data capture time 6.1

ER1, ER2, and ER3 equations 6.2

trigger (TRI Command) 6.2

EVENT Command

See Commands, EVE; Event

Event History

contents 6.2

HIS command

See Commands, HIS

retrieving history

application example 6.3

Event Report

column definitions 6.5Compressed ASCII CEVENT 6.4example event report 6.6

retrieving event data 6.3

summary section 6.7trigger 6.2

Event Summary

See also Event

contents 6.2

event type 6.2

EXI Command

See Commands, EXI

FFactory Assistance 12.15

FIL DIRECTORY Command

See Commands, FIL DIR

FIL READ Command

See Commands, FIL READ

FIL WRITE Command

See Commands, FIL WRITE

Firmware Versions A.1

Forms

See Meter

Front Panel

access levels 11.3automatic messages 11.2diagram 11.1, 11.3

display points 8.22layout 11.1LCD 11.2LEDs 11.1menus 11.2

set meter 11.7mount

dimensions 2.1

password 11.4pushbuttons 11.1, 11.3

GGrounding 2.9

HHarmonic Metering 4.22

See also Commands, MET H

distortion power 4.24K-Factor 4.24total harmonic distortion 4.24viewing 4.25

HISTORY Command

See Commands, HIS; Event History

IID Command

see Commands, ID

Input/Output

See Optoisolated Inputs; Output Contacts

Installation

dimensions 2.1, 2.3environment 2.3panel-mounting 2.1, 2.3physical location 2.3rack mounting 2.2

Instantaneous Metering

See Commands, MET

Internal Modem 10.1

IRIG Command

See Commands, IRI

IRIG-B 7.1

KK-Factor

See Harmonic Metering, K-Factor

KYZ Outputs 8.16See also TEST Mode

LLCD

See Front Panel

LDP

See Commands, LDP

LDP Command

See Commands, LDP; Load Profile

LEDs

front panel SET.8, 11.1targets 11.2

LMD

See Distributed Port Switch

IN.3IndexM–S


Load Profile

clearing 4.34determining the size of buffer 4.34report 4.32

Local Control Bit 8.9

LOOP Command

See Commands, LOO

MMAC Address

See Commands, VER

Maintenance Testing

See Testing

MATH Commands

See Commands, MAT

Maximum/Minimum Metering

See also Commands, MET M

update and storage 4.19viewing or resetting 4.19

Menus

See Front Panel, menus

MET

See Commands, MET

MET FL

See Commands, MET FL

MET H

See Commands, MET H

MET H A

See Commands, MET H A

MET H I

See Commands, MET H I

MET H M

See Commands, MET H M

MET H P

See Commands, MET H P

MET H V

See Commands, MET H V

MET PM

See Commands, MET PM

Meter

accuracy 1.9calibration 12.15forms 1.1

mounting 2.1view metering 10.22

METER Commands

See Commands, MET

METER CREST FACTOR Command

See Commands, MET CF

METER D Command

See Commands, MET D and MET D T

METER E Command

See Commands, MET E

METER H Command

See Commands, MET H

METER L Command

See Commands, MET L

METER M Command

See Commands, MET M

Meter Mounting

physical location 2.3

Meter Word Bits 9.2, D.1

function list 9.5

MIRRORED BITS G.1

See also Commands, LOO

Modbus RTU F.1register map F.11

Mounting

See Meter, mounting

Multidrop Network

See Modbus RTU

OOptoisolated Inputs

connections 2.11

debounce 2.11

Output Contacts

types 2.11

PPASSWORD Command

See Commands, PAS

Passwords

defaults 10.31front panel 11.4

Potential Transformer

input rating 2.12

Power Supply

connections 2.9fuse replacement 2.10voltage ranges 1.7

Predictive Demand 4.11

Processing Interval D.4

Processing Order D.4

Protocols

See Distributed Network Protocol (DNP3); Modbus RTU

PT

See Potential Transformer

PULSE Command

See Contact Outputs; Commands, PUL

Pulses

KYZ

See KYZ Outputs

Pushbuttons

diagram 11.3front panel 11.3

QQUIT Command

See Commands, QUI

RRemote Bits 8.4

See also Remote Control

Remote Control 8.4CONTROL Command

See Commands, CON

Reset

bit

See also Local Control Bit

demand metering 4.14targets 10.26

Rotating Display 8.22

SSchweitzer Engineering Laboratories

contact information 12.15

SEL-734 Meter

features 1.1options 1.1

Self Reads

See Time-of-Use

Self-Tests 12.12See also Testing

SELOGIC Control Equations D.1timers 8.9

Sequential Events Recorder

See SER (Sequential Events Recorder)

SER (Sequential Events Recorder)

See also Commands, SER

clearing report 6.9setting 6.8trigger 6.8view SER report 6.8

application example 6.9

SER Command

See Commands, SER

Serial Number Label 2.4, 2.5

Serial Ports

See also Communications, cables

EIA-232

See also Communications

front panel 11.1

EIA-485

See Communications

IN.4 IndexT–V


SET E Command

See Commands, SET E

Set Meter

using front panel 11.7

Settings

ASCII commands 10.13CT ratio 9.14date format 9.14enables 9.14from front panel 11.7from serial port 9.1meter ID 9.14phase rotation 9.14PT ratio 9.14serial port commands 9.1SET Command

See Commands, SET

structure 9.1terminal ID 9.14TERSE command 9.1TIME command

See Commands, TIM

SHO Command

See Commands, SHO

SNS Command

See Commands, SNS

Specifications 1.7, 1.9

SSI Command

See Commands, SSI

STA S

See Commands, STA S

STA SC

See Commands, STA SC

STA SR

See Commands, STA SR

Status 10.25See also Commands, CST;

Commands, STA

check meter status 12.12

STATUS Command

See Commands, STA

Status Failure 12.12

Status Warning 12.12

Synchrophasors

meter configuration 7.1

TTARGET Command

See Commands, TAR

Target LEDs

diagram 11.1

Terminal Blocks

tightening torque 1.9

TEST Mode 12.3

TEST MODE Command

See Commands, TEST MODE

Testing

See also TEST Mode

acceptance testing 12.1commissioning testing 12.2maintenance testing 12.2methods 12.9self-tests 12.12troubleshooting 12.13via front-panel 12.9with output contacts 12.10with SER 12.10

Thermal Demand Metering

See Demand Metering

TIM

See Commands, TIM

TIME Command

See Commands, TIM

Time Inputs 7.1

See also IRIG-B

connecting 7.1

Time-of-Use

billing data 5.9calendar

add an action 5.6

delete an action 5.7

demand reset 5.6

edit an action 5.7

self reads 5.6

data export 5.9glossary 5.11rate schedules

assign 5.5

create 5.3

delete 5.4

modify 5.4

register data

present season 5.9

previous season 5.9

self reads 5.9

setup 5.2

Timers

See SELOGIC Control Equations, timers

TOG Command

See Commands, TOG

Total Harmonic Distortion

See Harmonic Metering

Transformer/Line Loss Compensation

See also Commands, MET L

line losses 4.28viewing 4.26

TRIGGER Command

See Commands, TRI

Troubleshooting 12.13

VVERSION Command

See Commands, VER

Voltage Sag/Swell/Interrupt

report 6.10

Voltage Sag/Swell/Interruption

See also Commands, SSI



Access Level Command Description


0 BNA Binary names
















1 DAT Show date

1 DNP Show DNP map




















2


























1 TIM Show time



E DAT Set date



E LDP2 C– LDP12 C Reset second through twelfth load profile recorder





E TIM Set time



2 DNP Set DNP map





3


















2 SSI C Clear VSSI












0 BNA Binary names
















1 DAT Show date

1 DNP Show DNP map




















2


























1 TIM Show time



E DAT Set date



E LDP2 C– LDP12 C Reset second through twelfth load profile recorder





E TIM Set time



2 DNP Set DNP map





3


















2 SSI C Clear VSSI








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