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DELTAplus Meter User's Manual

1. 48 3 3 2 E 49 3 3 3 INTERNAL CLOCK cadets osea cesi ea noeh ONERE 49 A INSTAELATION xcii deiude odium oa Na bis eM NOR ad ND iR 50 4 1 AA LOI UIH U eomm 50 4 1 1 DIN RAIE MOUNTED 3 nre A 50 4 1 2 WALL MOUNTED niei age eee eee 50 4 1 3 FLUSH MOUNTED entente penes ene pna e BO 51 4 2 AVABOSI EXOS E WO IRR 52 4 2 1 DIRECT CONNECTED METERS once teet tacite tinto coder Chee conet 52 4 2 2 TRANSFORMER RATED METERS WITHOUT VOLTAGE 53 4 23 TRANSFORMER RATED METER WITH VOLTAGE TRANSFORMER 54 4 2 4 INPUTS OUTPUTS eee eia tee rented 55 4 2 5 INPUTS Saves R 55 4 2 6 PULSE OUTPUTS sicci E teo tea SEE 55 4 2 7 COMMUNICAT ION Chat See HER ESSE CHR PES ERR 55 43 INSTALLATION TEST 55 4 3 1 TEST JS 0 UDIB dU 56 4 3 1 1 Phas voltage presence test re ev ar tergo a evils 56 4 3 1 2 Phase connected to neutral 56 4 3 1 3 Power medsurement case eene
2. 24 2 7 3 7 Current 24 2 7 4 SETAMOBDE S C det A Le EL tut AMA IL tem 25 2 7 4 1 Current transformer ratio 25 2 7 4 2 Voltage transformer ratio VT 26 AA EP ED PADDED Page 2 of 137 DELTAplus meter User s Manual Rev TABLE OF CONTENTS 2 14 3 Pulse output frequency ete eere o E EE E EAE EE 26 2 7 4 4 Reset of energy 27 2 1 4 5 Primary address noscere D dete EROR 27 2140 Baud Tate ni eR DRE tese eite eiae REUS 28 214 WANG Heiss 2 RC adeguata 28 21 48 aho d dea e edi eee ees 30 2 74 9 Communication write access level 31 2 8 INSTRUMENTATION cscsscsssssssscsscsssccsssscescssssssssenessesnessosssssessssesessssnessesssssossssssessssnessessessesesssoes 32 2 9 AND OUTPUTS 0 ccsscssscsssssssccsscscescssscecsssnessssnsccsssssescnssnessssnessesssssosssssnssssssessessessesseseoes 33 2 9 1 FUNCTIONALITY OF INPUTS ae ethane 33 2 9 2 FUNCTIONALITY OF OUTPUTS eiii E EAE E 34 2 10 TARIFF Do 1d UM URP 34 2101 CONNECTIONSS d
3. Byte Size in bytes Value Description 96 1 CE DIF size 12 digit BCD storage number bit 0 97 1 AO DIFE tariff 2 storage number bit 1 4 unit bit 0 98 1 40 DIFE unit bit 1 99 1 04 VIF for units kvarh with resolution 0 01kvarh 100 105 6 XXXXXXXXXXXX Reactive energy tariff 2 106 1 CE DIF size 12 digit BCD storage number bit 0 107 1 BO DIFE tariff storage number bit 1 4 unit bit 0 108 1 40 DIFE unit bit 1 109 1 04 VIF for units kvarh with resolution 0 01kvarh 110 115 6 XXXXXXXXXXXX Reactive energy tariff 3 116 1 CE DIF size 12 digit BCD storage number bit 0 117 1 80 DIFE tariff bits 0 1 storage number bit 1 4 unit bit 0 118 1 50 DIFE tariff 4 unit bit 1 119 1 04 VIF for units kvarh with resolution 0 01kvarh 120 125 6 XXXXXXXXXXXX Reactive energy tariff 4 126 1 CE DIF size 12 digit BCD storage number bit 0 127 1 40 DIFE storage number bit 1 4 unit bit 0 128 1 FD VIF FD gt next VIFE specifies type of value 129 1 61 Cumulation counter 120 125 6 XXXXXXXXXXXX Number of pulses registered on input 1 126 1 CE DIF size 12 digit BCD storage number bit 0 127 1 80 DIFE storage number bit 1 4 unit bit 0 128 1 40 DIFE unit bit 1 129 1 FD VIF FD gt next VIFE specifies type of value 130 1 61 Cumulation counter 131 136 6 XXXXXXXXXXXX Number of pulses registered on input 2 137 1 1F DIF more records will follow in next telegram 138 150 13 000000000000000 PAD bytes
4. 56 of 137 DELTAplus meter User s Manual Rev 4 3 2 ERROR CODES Information about the errors in the form of error codes can be found in Alternative Mode Below is a list of all the error codes together with an error description and hints of what can be the cause of the errors Error Description 100 Phase 1 voltage is missing or low 101 Phase 2 voltage is missing or low 102 Phase 3 voltage is missing or low 123 Power in phase 1 negative Hints Current connections reversed Main current flowing in the wrong direction through current transformer Incorrect connection of phase voltages Current transformers connected to wrong current input 124 Power in phase 2 negative Hints Current connections reversed Main current flowing in the wrong direction through current transformer Incorrect connection of phase voltages Current transformers connected to wrong current input 125 Power in phase 3 negative Hints Current connections reversed Main current flowing in the wrong direction through current transformer Incorrect connection of phase voltages Current transformers connected to wrong current input 126 Total active power negative Hints One or more current connections reversed Main current flowing in the wrong direction through one or more current transformers Incorrect connection of phase voltages Current transformers connected to wrong current input 128 Ph
5. 74 137 DELTAplus meter User s Manual Rev The data together with information regarding coding length and the type of data is transmitted in data records The maximum total length of the data records is 234 bytes Data Record Header DRH Data Data Information Block DIB Value Information Block VIB Structure of a Data Record transmitted from left to right Each Data record consists of a data record header DRH and the actual data The DRH in turn consists of the data information block DIB to describe the length type and coding of the data and the value information block VIB to give the value of the unit and the multiplier Data Information Block DIB The DIB contains at least one byte Data Information Field DIF and is in some cases expanded with a maximum of 10 DIFE s Data Information Field Extension 3 Extension Function Field Data Field Bit Length and coding of data Structure of the Data Information Field DIF The Extension Bit is set when next byte is a DIFE The LSB of storage number is normally set to 0 to indicate actual value 1 stored value The Function Field is set to 00 for instantaneous values and 01 for maximum values The Data Field shows the format of the data Code Meaning Length in Byte 0 0000 No data 0001 8 Bit Integer 0010 16 Bit Integer 0100 32 Bit Integer 0111 64 Bit Integer 1010 4 digit BCD 1011 6 digit BCD 1100 8 digit BCD 1101
6. The network type symbol tells how many measurement elements the meter contains In each element one voltage and one current is measured and used in the energy measurement The energy in all elements is added to give the total energy consumption Meters with 1 2 and 3 elements exist see figure below 1 measuring element 2 measuring elements 3 measuring elements Fig 2 3 Network symbol Meters with 1 measuring element are used in single phase metering having a system with 2 wires Meters with 2 measuring elements are used in 3 phase metering having a system with 3 wires 2 watt meter method Meters with 3 measuring elements are used in 3 phase metering having a system with 4 wires 3 watt meter method 10 of 137 DELTAplus meter User s Manual Rev 2 3 2 DESIGNATION Below are tables with explanation for all positions in the type designation for the meters STANDARD METERS WITHOUT COMMUNICATION OPTION Type E Po Basic Measurement Communication Optional functionality Page 11 of 137 DELTAplus meter User s Manual Rev STANDARD METERS WITH M BUS COMMUNICATION Type Po Basic Measurement Communication Accuracy Voltage Page 12 of 137 DELTAplus meter User s Manual Rev STANDARD METERS WITH LONWORKS COMMUNICATION Type Basic Measurement Communication Accuracy Voltage Optional functi
7. 68 C5 C5 68 08 00 72 42 10 00 00 42 04 02 02 18 20 00 00 44 ED 24 00 00 AC OC 01 FD 25 3C CE 80 40 FD 61 52 23 00 00 00 00 C4 80 40 FD El 27 EA 00 00 00 C4 80 40 FD El A7 FF FE 02 94 01 00 00 C4 80 40 FD El A7 FF FE 01 16 00 00 00 C4 80 40 FD E1 A7 FF FE 04 07 07 00 00 C4 80 40 FD El A7 FF FE 01 00 00 00 C4 80 40 FD El A7 FF FE 02 26 00 00 00 C4 80 40 FD El A7 FF FE 02 1E 00 00 00 C4 80 40 FD El A7 FF FE 02 04 00 00 00 C4 80 40 FD El A7 FF FE 02 03 00 00 00 C4 80 40 FD El A7 FF FE 01 08 00 00 00 C4 80 40 FD El A7 FF FE 02 05 00 00 00 C4 80 40 FD El A7 FF FE 04 15 00 00 00 1 00 00 00 00 00 00 66 16 Sending request UD2 10 5b fe 59 16 Reading response 68 C5 C5 68 08 00 72 42 10 00 00 42 04 02 02 19 20 00 00 44 ED 24 00 0 AC 0 01 FD 25 3 CE 80 40 FD 61 78 49 00 00 00 00 C4 80 40 FD El A7 FF FE 00 00 00 C4 80 40 FD El A7 FF FE 04 19 02 00 00 C4 80 40 FD E1 A7 15 00 00 00 00 C4 80 40 FD E1 A7 15 00 00 00 00 C4 80 40 FD E1 A7 15 00 00 00 00 C4 80 40 FD E1 A7 15 00 00 00 00 C4 80 40 FD E1 A7 15 00 00 00 00 C4 80 40 FD E1 A7 15 00 00 00 00 C4 80 40 FD E1 A7 15 00 00 00 00 C4 80 40 FD E1 A7 15 00 00 00 00 C4 80 40 FD E1 A7 15 00 00 00 00 C4 80 40 FD E1 A7 15 00 00 00 00 1 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 6F 16 4 ED PADDED Page 114 of 137 DELTAplus meter User s Manual Rev 6 1 4 3 2 Read request and readout of maximum demand
8. 19 21 1 NORMAL MODE decks ii epe ce bt iei nv a peso a AER EE ERR 19 2 7 1 1 Energy display in Normal 20 2 12 ALTERNATIVE s Rate nies odes Glee als 20 2721 LCD eS m EE 21 2722 Error mformatiOD 21 2 7 2 Energy display in Alternative 21 272 4 Dranstobther tat iei mcer ero ertet tee eed 21 2 7 2 E TODA 21 2720 Baud tater cee 22 21 2171 Primary additess ice ene eese bet ete 22 2 7 2 8 Communication Status oni rod ice eget cect a 22 2729 io erro mentiti itt 22 2 7 2 10 noit EE 22 2 7 2 11 Ich m 22 2 7 2 12 Ie 22 2 7 2 13 Dr 22 2 7 2 14 23 2 7 2 15 Write protection 23 2 7 3 INSTRUMENTATION 23 DASA POW GR 23 24 32 NOWABE RE 23 2 1 3 55 24 2 7 3 4 Power factor ccccccccccssececsescecessseeecsenaececseeeeeecseeecseaaececseseecessaeeecnesaeeecseseeeesaeeeesesaeeecsesaeeesseeeeenes 24 21 39 Ac ve E m 24 ES MEd ui
9. ecu 56 4 3 2 ERROR CODES ep H 57 5 MEASUREMENT METHOD S 22ira aka xiii ax bk Ra daas iw lada aac 58 51 ACTIVE AND REACTIVE POWER eese esee entes testen tnn ta sins tn senten sess tuse tasse ta sens enses enses suse ta 58 5 2 SINGLE PHASE METERING eren eren eene 60 5 3 3 PHASE 2 ELEMENT METERING cesses sse ta sonata sensns ees suse 61 5 4 3 ELEMENT 65 5 5 68 6 COMMUNICATION i i 69 6 1 IMIS BUSS E 70 6 1 1 COMMUNICATION 5 70 6 1 2 PHYSICAL INTERFACE ione ei tete entered eos tope Sue P ydp rne 71 6 1 2 1 1 CC 71 612 2 Optional Oars C 71 6 1 3 PROTOCOL DESCRIPTION 72 S ES Telegram formats EE Et 72 6 1 3 1 1 Exeld descriptions 73 6 1 3 2 Conimu nication PLOCESS 79
10. AA 141 PADDED Page 55 of 137 DELTAplus meter User s Manual Rev and that will not be detected by the DELTAplus meter These combinations are however unusual and the check will discover a high percentage of all incorrect installations that occur in practice If any error is detected the Error segment is displayed and the OK segment is off If the meter detects total negative power the arrows will rotate backwards The error codes are read on the LCD in Alternative Mode 4 3 4 TEST PROCEDURE The tests made in the installation test are phase voltage presence and connection test and checking of the polarity of the active power Below is a description of these tests 4 3 1 1 Phase voltage presence test This test is done by measuring the element voltages and comparing it against predefined thresholds If the voltage is below this threshold it is assumed that the voltage is not present The result of this this test is reflected on the LCD phase voltage indicators 1 2 3 with a above referred to with 1 2 3 from now on LCD Error segment and in the error codes error code 100 102 A flashing 1 2 or 3 segment means the corresponding phase is low or disconnected 4 3 1 2 Phase connected to neutral test The meter checks if any of the phases are mixed up with the neutral It does this by comparing the ratio of the 3 phase voltages If any of the ratios are close to square root of 3 it signals this err
11. here eid ek ded rep dann beeline 87 6 1 4 2 15 power outage 87 6 1 4 2 16 Send pass word 87 6 1 4 2 17 Set pass words X 87 6 1 4 2 18 Set date and time 87 0 1 4 2 19 Set Caters sei iss sec 87 6 1 4 2 20 Reset maximum demand monthly values load profile or event 10 87 6 1 4 2 21 Freeze maximumi demand ek enar to Lee 87 6 1 4 222 Set write access level 87 6 1 4 2 23 Set tariff 87 6 1 4 2 24 Suppress LCD error display sess nent nennen 87 6 1 4 3 Reading data from the meter that require a read request command sss 87 6 1 4 3 1 Read request and readout of load profile 87 6 1 4 3 2 Read request and readout of maximum demand 87 6 1 4 3 3 Read request and readout of monthly values esee 87 6 1 4 3 4 Read request and readout of event log data 87 6 1 4 3 5 Read request and readout of current 1 87 6 1 4 4 Exror Information Hag ier deerit testet eot eed etn pete tre aero 87 6 1 5 INSTALLA MON mc 87 6 2
12. 2 7 2 12 Input stored status The input activity stored status is displayed as InPA1 X and InPA2 X where X is or 1 1 means voltage has at least once been applied to the input 2 7 2 13 Date In meters with internal clock the date is displayed as where is day month and year The 13 th of may 2007 will for example be displayed as d130507 22 of 137 DELTAplus meter User s Manual Rev If the date is not set d 5 displayed 2 7 2 14 Time In meters with internal clock the time is displayed as where is hours minutes and seconds The time 23 37 58 will for example be displayed as 23 37 58 If the time is not set is displayed 2 7 2 15 Write protection level The active write protection level is displayed In meters with internal clock some of the programmable parameters for the time dependant function can be write protected 3 different protection levels exist Open for write accesses displayed open by password for write accesses Open P displayed and closed for write accesses CLOSEd displayed 2 7 3 INSTRUMENTATION MODE In this mode it is possible to see additional information about the connected currents and voltages The nstrumentation Mode is reached from Alternative Mode by pressing the scroll button or activating the light sensor for more than two seconds long scroll The DE
13. Amplifier Input from current transformers Super capacitor HEIN Real time clock Voltage reference Microcontroller LCD EEPROM Reset circuit Red LED b EK Communication board connector Input Output board connector Scroll Pulse output kWh Fig 2 18 Main board block diagram delivered Pulse output The meter hardware options not included can be divided into the following parts o kvarh delivered A microcontroller that performs the energy measurement The device is calibrated via registers to fulfil the accuracy class requirements stated in IEC 62053 21 Besides the energy measurement it also contains functions for detecting low voltage power fail detecting absence of phase voltages measuring of voltage current power frequency and phase angles etc The microcontroller also handles the LCD the EEPROM the buttons the driving of the LED the communication and the pulse outputs etc Page 41 of 137 DELTAplus meter User s Manual Rev e AnLCbD liquid crystal display for display of accumulated energy transformer ratio pulse rate voltage current power status and error information etc e The current i
14. DELTAplus meter User s Manual Rev element voltages U1 U2 U3 U2 for a pure resistive load where the phase currents are in phase with its respective phase voltages The phase angles between the element voltages and the current by which it is multiplied is p32 where 12 which for a pure resistive load is 30 and 30 degrees If the phase voltages is 230 V and phase currents is 10 A the phase to phase voltages U1 U2 and U3 U2 will be 230 4 3 and the power in the 2 elements will be P1 230 43 10 cos 30 2 3450 W and P3 230 4 3 10 cos 30 3450 W U3 U2 U2 Fig 5 7 Vector diagram for 2 element meter with pure resistive load Below is another example with a vector diagram for a balanced inductive load with power factor 0 95 phase angle between voltage and current on each phase is arccos 0 95 18 2 degrees The phase angles between the element voltages and the current by which it is multiplied in this case is18 2 30 11 8 and 30 18 2 48 2 degrees If the phase voltages is 230 V and phase currents is 10 A the power in the 2 elements will be P1 2230 10 5 48 2 2655 3 P3 230 10 5 11 8 3899 5 W resulting in a total power of 2655 3 3899 5 6554 8 W 62 of 137 DELTAplus meter User s Manual Rev U3 U2 U3 U1 U2 932 11 8 U2 Fig 5 8 Vector diagram for 2 element meter with a balanced inductive load with power fac
15. Fig 2 20 Block diagram for 2outputs Microcontroller Interface and protection circuitry Output 2 Input 1 Fig 2 21 Block diagram for 1 input and The inputs consists of an optocoupler and interface circuitry towards the outside world The microcontroller inside the meter reads the status of the inputs via the optocouplers 2 versions exist for the input and input output boards one for low voltages max 40V and one for high voltages max 276 V The versions with 1 or 2 outputs handle both low and high voltages The input impedance on the inputs is resistive and has a resistance of 80 85 on the high voltage version and 8 13 on the low voltage version An input that is not connected left floating is the same as having voltage off The outputs consists of an optocoupler of solid state type They are built with MOSFET optocouplers with polarity independent outputs The equivalent circuitry of the outputs is an ideal relay in series with a resistor of typically 40 2 13 3 COMMUNICATION BOARDS The DELTAplus meter can be equipped with 3 different 2 wire communication option boards Lonworks PADDED Page 43 of 137 DELTAplus meter User s Manual Rev EIB Meter bus M bus The Lonworks board and EIB board contains a microcontroller handling the communication towards the external bus For M bus the communic
16. 00 00 16 Woo 00 00 61 61 61 61 00 00 82 95 08 21 00 00 03 03 04 04 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 Readout of 1 day of input 1 load profile interval values System sends read request command for input 1 interval values 68 OA OA 68 73 FE 51 02 Meter sends out acknowledge E5 System sends out request UD2 10 7B FE 79 16 Meter sends out data telegram 68 08 00 72 44 47 24 00 42 04 02 02 16 00 00 00 68 B8 44 ED 01 CE C4 C4 C4 C4 C4 C4 C4 C4 C4 C4 C4 C4 1 00 00 E2 ry Rod BB BA A A OA uS CO ee i ab BOO System sends out request UD2 10 5B B8 6A pipip icip ip ip rz f ND 59 16 EC F9 15 C5 04 86 16 Date and time 5 th of april year 06 00 00 for start of 1 st interval and of register value Interval length 60 minutes 00 00 C5 04 3C 61 04 01 00 00 El 27 0C 00 00 1 27 OE 00 00 1 27 OD 00 00 1 27 0C 00 00 1 27 OD 00 00 1 27 OD 00 00 El 27 OD 00 00 1 27 OD 00 00 1 27 OD 00 00 1 27 OD 00 00 1 27 OD 00 00 1 27 0C 00 00 00 00 00 00 00 00 00 00 00 00 Meter sends out data telegram 00 00 Register value at start
17. DELTAplus Meter User s Manual Rev C ABB Automation Technologies AB Box 1005 SE 611 29 NYKOPING Sweden Tel 46 155 295000 Fax 46 155 288110 Ak PADDED Page 1 of 137 DELTAplus meter User s Manual Rev TABLE OF CONTENTS TABLE OF CONTENTS jc 6 2 PRODUCT DESCRIPTION inna aoa 7 2 1 BA MIL OVERVIEW E P 7 2 2 METER PARTS wisscccossecsesasesssesisonssedasenscesdevecsecesassesdcosceasessecassobsestadevonssesasaeseddasceosesassassoussonsseddsonseddevesesees 8 2 3 METER TYPES c 9 2 3 1 NETWORK occ oe Less ees ecco eek I 10 2 3 2 TYPE DESIGNATION ener tU texts ir ee eM eere 11 2 4 ENERGY INDICATOR 15 2 5 15 2 5554 SEV BU TION eL wn 15 2 5 12 SCROLL BUTTON LIGHT SENSOR 15 2 6 DISPLAY INFORMATION 16 2 6 1 DISPLAY OVERVIEW 17 2 6 2 VOLTAGE INDICAT ORS ve eee 17 2 6 3 OK AND ERROR SYMBOLS 17 2 6 4 7 SEGMENT 7 CHARACTERS AND UNIT 18 2 6 5 INDICATION OF ACTIVE 18 2 6 6 LOAD INDICATOR 18 2 7 DISPLAY MODES ec S
18. Ohex 0 W CE 00 ED 6B 00 00 00 00 00 00 Date time stamp all zeros gt no maximum have been stored for this tariff D4 30 29 50 30 02 00 CE 00 ED 6B 00 45 03 07 06 06 D4 80 10 29 04 00 CE 00 ED 6B 55 59 23 30 06 06 D4 90 40 29 AO AO 00 00 Maximum demand storage number 1 for reactive power tariff 1 VIF 29 gt data in var with 2 decimals Data AOAOhex 411 20 var CE 00 ED 6B 26 29 01 03 06 06 Date time stamp for maximum given above 3 rd of june 2006 01 29 26 hour minute second D4 AO 40 29 00 00 00 00 CE 00 ED 6B 00 00 00 00 00 00 D4 BO 40 29 30 89 00 00 CE 00 ED 6B 00 45 03 07 06 06 D4 80 50 29 AO 31 01 00 CE 00 ED 6B 55 59 23 30 06 06 D4 40 FD 61 00 00 00 00 demand storage number 1 for input 1 29 gt data in number of pulses Data Ohex 0 pulses CE 00 ED 6B 00 00 00 00 00 00 D4 80 40 FD 61 00 00 00 00 CE 00 ED 6B 00 00 00 00 00 00 CE 00 ED EB FF 70 00 00 00 01 07 06 Date time stamp for end of measurement period 1 st of july 2006 00 00 00 hour minute second 1F 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 C5 16 System sends out request UD2 10 7B FE 79 16 Meter sends out data telegram 68 E8 E8 68 08 00 72 44 47 24 00 42 04 02 02 06 00 00 00 01 FD 25 OF 94 11 29 80 81 08 00 Maximum demand storage number 2 for active power tariff 1 29 gt data in W with 2 decimals Data 88180hex 5574 40 W 01 ED 6B 00 00 01 19 05 06 Date time stamp for ma
19. Parameters controlling the functionality of the internal clock and the time dependant functions can be programmed into the meter via the infrared optical port or the M bus interface in meters equipped with electrical M bus interface Program for setting these parameters is supplied by ABB 2 12 1 INTERNAL CLOCK The internal clock have a built in calendar and automatically keeps track of leap year and daylight savings time DST Use of DST is optional Backup of the clock during power failure is done with a super capacitor The time is controlled from a quartz crystal based real time clock Time and date is set via the buttons for details see chapter 2 7 4 7and 2 7 4 8 or via communications for details see chapter 6 The internal clock is approved according to the standard IEC 62054 21 which contains particular requirements for time switches The stated accuracy is less than 5 ppm at room temperature when controlled from the quartz crystal based real time clock 2 12 2 MONTHLY VALUES At every monthly change all energy register and input counter values are stored together with a date time stamp All total energy values are stored and in tariff meters also the tariff registers are stored 36 of 137 DELTAplus meter User s Manual Rev If the meter is powered during a monthly change the time stamp will be 00 00 00 and the date stamp the 1 st of the month entered If there is a power fail during the monthly chang
20. Value Description 60 1 02 DIF size 2 byte integer 61 1 FF VIF next byte is manufacturer specific 62 1 ED VIFE current harmonics 63 1 FF VIF next byte is manufacturer specific 64 1 8x VIFE phase x 65 1 FF VIF next byte is manufacturer specific 66 1 F8 Extension of manufacturer specific vife s next vife s used for numbering 67 1 05 Harmonic number 68 69 2 XXXX 5 th harmonic in percent with 1 decimal 70 1 02 DIF size 2 byte integer 71 1 FF VIF next byte is manufacturer specific 72 1 ED VIFE current harmonics 73 1 FF VIF next byte is manufacturer specific 74 1 8x VIFE phase x 75 1 FF VIF next byte is manufacturer specific 76 1 F8 Extension of manufacturer specific vife s next vife s used for numbering 77 1 05 Harmonic number 78 79 2 XXXX 5 th harmonic in percent with 1 decimal 80 1 02 DIF size 2 byte integer 81 1 FF VIF next byte is manufacturer specific 82 1 ED VIFE current harmonics 83 1 FF VIF next byte is manufacturer specific 84 1 8x VIFE phase x 85 1 FF VIF next byte is manufacturer specific 86 1 F8 Extension of manufacturer specific vife s next vife s used for numbering 87 1 05 Harmonic number 88 89 2 XXXX 5 th harmonic in percent with 1 decimal 90 1 02 DIF size 2 byte integer 91 1 FF VIF next byte is manufacturer specific 92 1 ED VIFE current harmonics 93 1 FF VIF next byte is manufacturer specific 94 1 8x VIFE phase x 95 1 FF VIF next byte is manufacturer specific 96 1 F8 Extension of man
21. s Manual Rev The meter will remain selected until it receives a selection command with non matching secondary addresses a selection command with Cl 56h or a SND NKE to address 253 6 1 4 TELEGRAMS The communication can be divided in two parts One part is reading data from the meter and the other part is sending data to it This section describes telegrams sent to and received from the DELTAplus meter The data readout procedure starts when the master sends a REQ_UD2 telegram to the meter The meter responds with a RSP_UD telegram A typical readout is a multi telegram readout The last DIF in the user data part of the telegram is 1F to indicate that there is more data in the next telegram For DELTAplus meters there are at least 3 telegrams to read In meters with internal clock there are more telegrams to read where the most recent monthly values will be sent out in telegram 4 the 2 nd most recent monthly values in telegram 5 if it exist and so on until all stored montly values have been read If no monthly values exist in a meter with internal clock all data in the 4 th telegram will be marked with status byte signifying no data available 15 hex Data for load profile maximum demand and event log are read by first sending a read request command and then sending a REQ_UD2 telegram to the meter The meter then responds with a telegram containing the requested data It is also possible to read out monthly values using this met
22. 1 the displayed values in Normal mode is shifted step to the left for every factor of 10 in the transformer ratio settings see below Transformer ratio Energy format displayed CT x VT lt 10 kWh kvarh 1 decimal 10 lt CT x VT lt 100 kWh kvarh without decimal 100 CT x VT 1000 MWh Mvarh 2 decimals 1000 CT x VT 10 000 MWh Mvarh 1 decimal CT x VT gt 10 000 MWh Mvarh without decimal The figure below shows an example where the reactive energy unit kvarh is displayed when the transformer ratio is 50 Fig 2 14 Display of reactive energy with CT VT 50 The internal meter energy registers are kept in secondary form and multiplied by the programmed transformer ratios and displayed on the LCD in primary form in Normal mode 2 7 2 ALTERNATIVE MODE The Alternative Mode is reached from Normal Mode by pressing the scroll button or activating the light sensor for more than two seconds long scroll Page 20 of 137 DELTAplus meter User s Manual Rev The DELTAplus meter indicates being in Alternative mode by the triangle being permanently lit If no button is pressed after entering Alternative mode the different display items will be automaticaly displayed one ata time in sequence If the scroll button is pressed shortly it single steps hand symbol C on and each item can be viewed longer time Below is described the information shown i
23. 51h Data send 52h Selection of slaves B8h Set baud rate to 300 baud B9h Set baud rate to 600 baud BAh Set baud rate to 1200 baud BBh Set baud rate to 2400 baud BCh Set baud rate to 4800 baud BDh Set baud rate to 9600 baud Cl field codes to use by the master The meter uses code 72h in the Cl field for responses to requests for user data User Data The User Data contains the data to be sent to the recipient Fixed Data Header Data Records MDH 12 Byte variable number of bytes 1 Byte Structure of the User Data meter to master Data Records variable number of bytes Structure of the User Data master to meter Fixed Data Header Identification No Access No 1 Byte Structure of the Fixed Data Header e Identification Number is the 8 digit serial number of the meter BCD coded e Manufacturer is set to 0442h meaning ABB e Version specifies the version of the protocol implementation 2 different protocol versions exist for DELTAplus meters 2 and 5 Minor differences can exist between the 2 different versions If so they are mentioned in this manual e Medium byte is set to 02h to indicate electricity e Access Number is a counter that counts successful accesses e Status byte is used to indicate the meter status Internal error Power low Permanent error Installation error NOT USED ELTAplus meter specific 0 1 2 3 4 Temporary error 5 6 7 D e Signature is set to 00 00 Data Records
24. Day of week data in bit 1 3 001 111 Monday Sunday Daytype data in bit 4 5 00 11 Daytype 1 4 Season data in bit 6 7 00 11 Season 1 4 149 1 07 DIF size 64 bit integer 150 1 FD VIF extension of VIF codes 151 1 17 VIFE error flags binary 152 159 8 64 Error flags 160 1 01 DIF size 8 bit integer 161 1 FF VIF next byte is manufacturer specific 162 1 18 VIFE Power fail counter 163 1 XX Power fail counter 164 1 OE DIF size 12 digit BCD 165 1 FF VIF next byte is manufacturer specific 166 1 6C VIFE Power outage timer 167 172 6 XXXXXXXXXXXX Power outage time sec min hour days 150 first AL 4 PADDED Page 83 of 137 DELTAplus meter User s Manual Rev Example of the 1 telegram continued all values are hexadecimal 173 1 00 DIF size variable length ASCII coding 174 1 FD VIF extension of VIF codes 175 1 Firmware 176 1 08 Byte specifying length see note below 177 184 8 XXXXXXXXXXXXXXXX Firmware version ASCII coded Isb byte first see note below 185 1 1F DIF more records will follow in next telegram 186 205 20 000000000000000 PAD bytes 000000000000000 0000000000 206 1 XX CS checksum calculated from C field to last data 207 1 16 Stop character Note regarding firmware version In firmware version 3 17 and above it is sent out with 8 ASCII characters as Dabc def where D stands for DELTAplus is the total fir
25. InPA1 X and InPA2 X where X 1 0 or 1 1 means voltage has at least once been applied to the input Page 33 of 137 DELTAplus meter User s Manual Rev The stored status can be reset via the communications bus On meters with internal clock and inputs the following additional functions for the inputs can be used Load profile monthly values and maximum demand For information regarding these functions see sections describing these functions 2 9 2 FUNCTIONALITY OF OUTPUTS The outputs are controlled via communication or via the internal clock The status of the outputs can be read via the communication bus When the outputs are controlled via communication the status of the outputs is saved at a power failure and restored at power up The output relays are always open if the meter is not powered 2 10 TARIFF INPUTS DELTAplus meters with tariff functionality option have the tariffs controlled either via communication the internal clock or by 1 or 2 tariff inputs Tariff control via inputs are done by applying a proper combination of voltage or no voltage to the input s Each combination of voltage no voltage will result in that the meter will register the energy in a particular tariff register In combined meters with both active and reactive metering both quantities are controlled by the same inputs and the active tariff for the active and reactive energy will always be the same 2 10 1 CONNECTIONS The
26. Indicates that The symbol for a non Alternative or Load indicator the arrows rotate at a constant speed when Measuring units active tariff remains lit Instrumentation mode when its value is is active being displayed current is flowing in any phase Fig 2 6 DELTAplus meter LCD 2 6 2 VOLTAGE INDICATORS Fig 2 7 Voltage indicators These indicate voltage element presence absence where a blinking segment means voltage absent and a segment in a steady on state means voltage present 2 6 3 AND ERROR SYMBOLS Fig 2 8 Status symbols The OK and Error segments constantly indicate the overall status of the meter Only one of the segments is lit at a time Besides indicating the status of the meter itself they are also used to indicate the result of an installation check which is a function where the meter itself every second checks the installation If the result of the installation check detected no errors and no meter errors are pending the OK symbol is on If an installation error was detected or a meter error is pending the Error symbol is on The error segment will be kept on as long as any error is pending Page 17 of 137 DELTAplus meter User s Manual Rev Information regarding pending errors can be viewed in alternative mode where each error have an error code Installation errors lies between 100 128 and date and time error have error code 140 and 141 Internal meter erro
27. Valid values 0 99 All other bits are unused 14 1 XX CS checksum calculated from C field to last data 15 1 16 Stop character This command is affected by the write protection level set Note that the seconds are not included in this command 6 1 4 2 19 Set date The date is set by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 07 L field calculated from C field to last user data 3 1 07 L field repeated 4 1 68 Start character 5 1 53 73 C field SND_UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 02 DIF size 16 bit integer 9 1 6C VIF date 10 11 1 XXXX Date day month year coded accorded to M bus datatype G 12 1 XX CS checksum calculated from C field to last data 13 1 16 Stop character This command is affected by the write protection level set Page 103 of 137 DELTAplus meter User s Manual Rev 6 1 4 2 20 Reset maximum demand monthly values load profile or event log All data for maximum demand monthly values load profile or event log is cleared by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 08 L field calculated from C field to last user data 3 1 08 L field repeated 4 1 68 Start character 5 1 53 73 C field SND_UD 6 1 A fi
28. Value Description 96 1 8E DIF size 12 digit BCD 97 1 DIFE tariff 3 98 1 40 DIFE unit 2 99 1 04 VIF for units kvarh with resolution 0 01kvarh 100 105 6 XXXXXXXXXXXX Reactive energy Tariff 3 106 1 8E DIF size 12 digit BCD 107 1 80 DIFE 108 1 50 DIFE tariff 4 unit 2 109 1 04 VIF for units kvarh with resolution 0 01kvarh 110 115 6 XXXXXXXXXXXX Reactive energy Tariff 4 116 1 01 DIF size 8 bit integer 117 1 FF VIF next byte is manufacturer specific 118 1 13 VIFE current tariff 119 1 XX Current tariff 120 1 0C DIF size 8 digit BCD 121 1 FF VIF next byte is manufacturer specific 122 1 12 VIFE transformer ratio 123 125 3 XXXXXX Transformer ratio 126 1 0A DIF size 4 digit BCD 127 1 FF VIF next byte is manufacturer specific 128 1 68 VIFE current transformer ratio 129 130 2 XXXX Current transformer ratio 131 1 0A DIF size 4 digit BCD 132 1 FF VIF next byte is manufacturer specific 133 1 69 VIFE voltage transformer ratio 134 135 2 XXXX Voltage transformer ratio 136 1 DIF size 12 digit BCD 137 1 6D VIF time date 138 143 6 XXXXXXXXXXXX Time and date sec min hour day month year 144 1 01 DIF size 8 bit integer 145 1 FF VIF next byte is manufacturer specific 146 1 9 VIF extension of manufacturer specific vife s next vife specifies actual meaning 147 1 01 VIF DST day of week day type season 148 1 DST day of week day type season DST data in bit 0 1 DST active 0 DST inactive
29. lt 50 lt number distorsion distorsion distorsion distorsion distorsion lt 5 lt 10 lt 20 50 96 100 95 2 0 5 1 0 96 2 4 2 3 0 7 1 596 3 6 3 4 t 1 0 96 t 2 0 96 4 8 4 5 1 2 2 5 96 5 10 5 6 1 596 3 0 96 6 12 95 6 7 1 7 3 5 7 14 7 8 t 2 0 96 4 0 96 8 16 8 9 25 t 5 0 96 t 10 96 t 2096 t 1096 For distorsion levels below 1 96 there s an absolute uncertainty of 0 5 96 The accuracy of the total harmonic distorsion will vary as it is dependant on all harmonics present which in turn have different accuracy and also amplitude depndant accuracy For information regarding presentation of the instrumentation values on the LCD see section 2 7 3 For information regarding communication formats of the instrumentation values on the LCD see chapter 6 As mentioned above the current harmonics 2 9 together with the fundamantal is measured sequentially one at a time approximately 1 harmonic each second Each harmonic is calculated according to I 2 100 and the total current harmonic distorsion for the harmonics measured is calculated according to 9 IY 721 100 n 2 where I is the fundamental current and is the current for harmonic with number n Page 32 of 137 DELTAplus meter User s Manual Rev At each measurement the harmonic is set to 0 if the rms value of the current is below a certain lower limit no
30. 00 00 00 00 00 00 00 00 00 00 00 00 00 56 16 Checksum and stop byte System sends out request UD2 10 5B FE 59 16 Meter sends out data telegram 68 9E 9E 68 08 00 72 44 47 24 00 42 04 02 02 21 00 00 00 Data header 44 ED 6A 00 C5 04 Date and time 5 th of april year 06 12 00 for start of 1 st interval and of register value 01 FD 25 3 Interval length 60 minutes 04 39 26 00 00 00 00 Register value at start of 1 interval in telegram 26 39 kWh Page 110 of 137 DELTAplus meter User s Manual Rev Wp RP RRR DP PB 7 2 2 2 7 7 7 7 7 2 2 2 2 2 2 0 0 7 7 J J 5 0 0 B8 9D CA FE 04 04 03 FE FF Bl CF 96 A9 9E A8 00 00 FE FE 03 03 04 02 04 04 00 00 00 00 02 00 00 ftsstinterval value Consumption 0 750 kWh 2 hex manufacturer specific status 02 interval short 03 00 00 04 00 00 12 th interval value Consumption 1 192 kWh 4A8 hex 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 Readout of 1 day of input 1 load profile register values System sends read request command for input 1 register values 68 0A 0A 68 73 FI E 51 02 EC FF F9 14 C5 04 85 16 Meter sends out acknowledge P E5 System sends out request UD2 10 7B E 79 16 Meter sends out data telegram 00 72 44 47 24 00
31. 00000000000 151 1 XX CS checksum calculated from C field to last data 152 1 16 Stop character AA EDEB PADDED Page 93 of 137 DELTAplus meter User s Manual Rev 6 1 4 2 Sending data to the meter Below are described telegrams possible to send to the DELTAplus meter Some telegrams contain data and some not Data sent in the telegram are sometimes stored in the meter sometimes used by the meter when performing a certain action Telegrams containing no data usually initiates a certain action in the meter Some of the commands can be protected by a password or be closed completely 3 levels of write protection exist Open open by password and closed In the level open the meter will always accept the command if the meter is correctly addressed and the syntax and checksum is correct In the level open by password the command must be preceded by a send password command see section 6 1 4 2 16 directly followed by the command in order for the meter to accept the command In the level closed it will never accept the command Note that the meter will answer with an acknowledge character E5 hex even if it is closed The acknowledge character only signifies that the meter was correctly addressed and that the syntax and checksum was correct The protection level can be set via the buttons see section 2 7 4 9 or via the command set write access level see section 6 1 4 2 22 Information reg
32. 01 VIFE 11 30 31 2 XXXX Power factor L1 32 1 02 DIF size 16 bit integer 33 1 FF VIF next byte is manufacturer specific 34 1 EO VIFE power factor with resolution 0 001 35 1 FF VIFE next byte is manufacturer specific 36 1 02 VIFE L2 37 38 2 XXXX Power factor L2 39 1 02 DIF size 16 bit integer 40 1 FF VIF next byte is manufacturer specific 41 1 EO VIFE power factor with resolution 0 001 42 1 FF VIFE next byte is manufacturer specific 43 1 03 VIFE L3 44 45 2 XXXX Power factor L3 46 1 02 DIF size 16 bit integer 47 1 FF VIF next byte is manufacturer specific 48 1 52 VIFE phase angle power with resolution 0 1 49 50 2 XXXX Phase angle power Total 51 1 02 DIF size 16 bit integer 52 1 FF VIF next byte is manufacturer specific 53 1 D2 VIFE phase angle power with resolution 0 1 54 1 FF VIFE next byte is manufacturer specific 55 1 01 VIFE L1 56 57 2 XXXX Phase angle power L1 58 1 02 DIF size 16 bit integer 59 1 FF VIF next byte is manufacturer specific 60 1 D2 VIFE phase angle power with resolution 0 1 61 1 FF VIFE next byte is manufacturer specific 62 1 02 VIFE L2 63 64 2 XXXX Phase angle power L2 EP ED PADDED Page 88 of 137 DELTAplus meter User s Manual Rev Example of the 3 telegram continued all values are hexadecimal Byte No Size in bytes Value Description 65 1 02 DI
33. 1 68 Start character 2 1 0A L field calculated from C field to last user data 3 1 0A L field repeated 4 1 68 Start character 5 1 53 73 C field SND UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 0 DIF size 8 digit BCD 9 1 FF VIF next byte is manufacturer specific 10 1 12 VIFE transformer ratio 11 14 4 XX XX XX XX New transformer ratio 15 1 XX CS checksum calculated from C field to last data 16 1 16 Stop character This command is not accepted by a direct connected meter This command is not affected by the write protection level set 6 1 4 2 8 Select status information Normally the DELTAplus meter sends out the status information as the last VIFE only if it is not equal to zero It is also possible to make the meter to always send out the status information as last vife or to make it to never send out the status information To change the way the status information is sent out the following command is sent all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 07 L field calculated from C field to last user data 3 1 07 L field repeated 4 1 68 Start character 5 1 53 73 C field SND_UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 01 DIF size 8 bit integer 9 1 FF VIF next byte is manufacturer specific 10 1 15 VIFE status of values status byte on the values 11 1 XX 0 never
34. 1 68 Start character 5 1 53 73 C field SND_UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 80 DIF size no data 9 80 DIFE unit 0 10 1 40 DIFE unit 2 11 1 FD VIF extension of VIF codes 12 1 1 cumulating counter 13 1 07 VIFE clear 14 1 XX CS checksum calculated from C field to last data 15 1 16 Stop character This command is not affected by the write protection level set Page 99 of 137 DELTAplus meter User s Manual Rev 6 1 4 2 13 Set output 1 Setting the state of output 1 is done by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 08 L field calculated from C field to last user data 3 1 08 L field repeated 4 1 68 Start character 5 1 53 73 C field SND_UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 81 DIF size 8 bit integer 9 1 40 DIFE unit 1 10 1 FD VIF extension of VIF codes 11 1 1A VIFE digital output 12 1 XX Output 1 new state 13 1 XX CS checksum calculated from C field to last data 14 1 16 Stop character This command is not affected by the write protection level set 6 1 4 2 14 Set output 2 Setting the state of output 2 is done by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character
35. 2 1 09 L field calculated from C field to last user data 3 1 09 L field repeated 4 1 68 Start character 5 1 53 73 C field SND UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 81 DIF size 8 bit integer 9 1 80 DIFE unit 0 10 1 40 DIFE unit 2 11 1 FD VIF extension of VIF codes 12 1 1A VIFE digital output 13 1 XX Output 2 new state 14 1 XX CS checksum calculated from C field to last data 15 1 16 Stop character This command is not affected by the write protection level set Page 100 of 137 DELTAplus meter User s Manual Rev 6 1 4 2 15 Reset of power outage time Reset of power outage time is done by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 07 L field calculated from C field to last user data 3 1 07 L field repeated 4 1 68 Start character 5 1 53 73 C field SND_UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 00 DIF size no data 9 1 VIF next byte is manufacturer specific 10 1 EC VIFE power outage time 11 1 07 VIFE Clear 12 1 XX CS checksum calculated from C field to last data 13 1 16 Stop character This command is not affected by the write protection level set 6 1 4 2 16 Send password Password is sent by the following command all values are hexadecimal Byte
36. 42 04 02 02 12 00 00 00 Data header 6 4 0 CE H C00000Q000000 rj Bi pd Dd Bd Bd Bd Bd Bd d d 3 8 4 1 hn B9 ED FD 40 aa UUUUUUUUUU lu 9 6B 2 eo 5 D 68 00 3C 61 OY 08 01 16 C5 04 L 00 Date and time for first register value in telegram end of 1 st interval Interval length 60 minutes 00 00 00 Register value end of 1 st interval 161 pulses status not sent gt status 0 00 00 00 Register value 130 pulses 00 00 00 Register value 220 pulses More data exist 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 System sends out request UD2 10 5B FI E 59 16 Meter sends out data telegram 68 B9 B9 68 08 00 72 44 47 24 00 42 04 02 02 13 00 00 00 44 ED 6B 00 OD C5 04 01 FD 25 3C CE 40 FD 61 71 02 00 00 00 00 CE 40 FD 61 88 02 00 00 00 00 CE 40 FD 6105 03 00 00 00 00 CE 40 FD 61 18 03 00 00 00 00 40 FD 61 31 03 00 00 00 00 40 FD 61 44 03 00 00 00 00 CE 40 FD 61 56 03 00 00 00 00 40 FD 61 69 03 00 00 00 00 AA EP ED PADDED Page 111 of 137 DELTAplus meter User s Manual Rev 40 40 40 40 rj p Ed Dd Dd
37. LSB first 8 1 DIF size no data storage number 1 9 1 80 DIFE unit 0 10 1 40 DIFE unit 2 11 1 FD VIF extension of VIF codes 12 1 9B VIFE digital input 13 1 07 VIFE clear 14 1 XX CS checksum calculated from C field to last data 15 1 16 Stop character This command is not affected by the write protection level set Page 98 of 137 DELTAplus meter User s Manual Rev 6 1 4 2 11 Reset of input counter 1 Reset of input counter 1 is done by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 08 L field calculated from C field to last user data 3 1 08 L field repeated 4 1 68 Start character 5 1 53 73 C field SND UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 80 DIF size no data 9 1 40 DIFE unit 1 10 1 FD VIF extension of VIF codes 11 1 E1 VIFE cumulating counter 12 1 07 VIFE clear 13 1 XX CS checksum calculated from C field to last data 14 1 16 Stop character This command is not affected by the write protection level set 6 1 4 2 12 Reset of input counter 2 Reset of input counter 2 is done by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 09 L field calculated from C field to last user data 3 1 09 L field repeated 4
38. Size in bytes Value Description 1 1 68 Start character 2 1 OA L field calculated from C field to last user data 3 1 0 L field repeated 4 1 68 Start character 5 1 53 73 C field SND_UD 6 1 A field address 7 1 51 Cl field data send LSB first 8 1 02 DIF size 2 byte integer 9 1 VIF time point date M bus data type G 10 1 FF VIF next byte is manufacturer specific 11 1 9 VIF extension of manufacturer specific vife s next vife specifies actual meaning 12 1 19 VIFE specifies monthly values 13 14 2 XXXX Date M bus data type G 15 1 XX CS checksum calculated from C field to last data 16 1 16 Stop character The format for the date is M bus data type G which consist of 2 bytes coded according to the following Day in bits 0 4 Valid values 1 31 Month in bits 8 11 Valid values 1 12 Year in bits 5 7 and bits 12 15 bit 5 7 is the Isb bits Valid values 0 99 Example 23 rd september 2006 23 9 06 will be coded as bit 15 0 0000 1001 1101 0111 in binary format which will be 09D7 in hexadecimal format If no data is stored in the meter for the specified date it will send out data from the nearest date backwards in time If no monthly values is stored in the meter equal or older than the specified date all data in the telegram will have status byte marked as no data available 15 hex After having read a telegram of monthly values it is possible to continue to read next stored telegram with monthly valu
39. Valid values 0 99 All other bits are unused All fields have binary coding When the load profile data is read out as consumption per interval the date time information specifies the start of the 1 st interval and the date time stamp for the regsiter value in the frame sent out When the load profile data is read out as register values the date time information specifies the end of the 1 st interval the frame sent out It is also possible to start reading data within a day by sending the following read request command containing both date and time all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 OE L field calculated from C field to last user data 3 1 OE L field repeated 4 1 68 Start character 5 1 53 73 C field SND_UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 DIF size 6 byte bcd 9 1 ED VIF time date 10 1 FF VIF next byte is manufacturer specific 11 1 9 VIF extension of manufacturer specific vife s next vife specifies actual meaning 12 1 XX VIFE specifies data requested 10 Active energy register values at end of interval 11 Active energy consumption per interval 12 Reactive energy register values at end of interval 13 Reactive energy consumption per interval 14 Input 1 register values at end of interval 15 Input 1 number of counts per interval 16 Input 2 register values at end of interval 17
40. be sent out with 5 events in each telegram If less than 5 events is stored in the meter for the specified date time and offset all data in the telegram after the last stored event will have status byte marked as no data available 15 hex After having read a telegram with events it is possible to continue to read events by continue sending REQ_UD2 s The last DIF in the telegram tell if there are more events or not 1F hex when more data exists and OF hex if no more data exist The data sent out for each event is e Event type 1 byte binary coded The different types of events that can be stored are listed below e Date time stamp for start of the event 6 byte bcd in order sec min hour day month year e Duration of the event 4 byte binary coded Event types No event available Total power outage Power outage on phase 1 Power outage on phase 2 Power outage on phase 3 Overvoltage on phase 1 AA EP ED Page 120 of 137 DELTAplus meter User s Manual Rev 6 Overvoltage on phase 2 7 Overvoltage on phase 3 8 Undervoltage on phase 1 level 1 9 Undervoltage on phase 2 level 1 10 Undervoltage on phase 3 level 1 11 Undervoltage on phase 1 level 2 12 Undervoltage on phase 2 level 2 13 Undervoltage on phase 3 level 2 14 Not used 15 Abnormal negative power 16 THD current above trip level If the data item read is normal with no specific status associated w
41. button is not pressed during this time the DELTAplus meter does an Escape and steps one activity back and continues doing so until Normal Mode is reached again If the scroll button is pressed for more than ten seconds the DELTAplus meter ignores it 2 6 DISPLAY INFORMATION From the display you can get all the information such as energy consumption active settings error status etc The most important information is either displayed continuously or automatically displayed sequentially one quantity at a time Information that is not necessary to be viewed all the time can be displayed by using either the button or the light sensitive sensor The display is two inches wide and has up to 7 characters with a height of 7 mm The illustration below shows all segments forming characters and symbols that can appear on the display in different display modes Note In every mode the energy continues to be measured the energy registers are updated and the meter generates pulses 16 of 137 DELTAplus meter User s Manual Rev 2 61 DISPLAY OVERVIEW Indicates single step mode and set mode active Voltage indicators OK and Error L1 L2 L3 symbol Active energy Indicates primary recording Reactive energy indicator indicator Normally not 1 Normally Values Tariff symbols the symbol for active tariff flashes
42. data Read request of maximum demand is done by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 OA L field calculated from C field to last user data 3 1 0 L field repeated 4 1 68 Start character 5 1 53 73 C field SND_UD 6 1 A field address 7 1 51 Cl field data send LSB first 8 1 02 DIF size 2 byte integer 9 1 VIF time point date M bus data type G 10 1 FF VIF next byte is manufacturer specific 11 1 9 VIF extension of manufacturer specific vife s next vife specifies actual meaning 12 1 18 VIFE specifies maximum demand 13 14 2 XXXX Date M bus data type G 15 1 XX CS checksum calculated from C field to last data 16 1 16 Stop character When sending the read request a date is specified in the data The meter then sends out the maximum demand data that have equal or older end of measurement period date time stamp starting with the data that are nearest in time compared to the date in the command The format for the date is M bus data type G which consist of 2 bytes coded according to the following Day in bits 0 4 Valid values 1 31 Month in bits 8 11 Valid values 1 12 Year in bits 5 7 and bits 12 15 bit 5 7 is the Isb bits Valid values 0 99 Example 23 rd september 2006 23 9 06 will be coded as bit 15 0 0000 1001 1101 0111 in binary format which will be 09D7 in hexad
43. inside of the covers there are wiring diagrams for all terminals covered by the sealable cover Position 5 Meter type label Label with important information about the meter Position 6 Sealing tape A piece of tape sealing the meter which will leave traces on the meter in case it is broken Position 7 Light sensor The meter has a light sensor which can be used to view different information in the meter Position 8 LED The meter has a red Light Emitting Diode that flashes in proportion to the consumed energy Position 9 Pulse output s or communication Page 8 of 137 DELTAplus meter User s Manual Rev Here the meter has terminals for either pulse output s or communication M bus or LON purposes Position 10 See position 4 Position 11 Terminal block All the voltages and currents sensed by the meter are connected here Position 12 Space for ownership marking A small label marking ownership can be inserted here Position 13 LCD A 7 digit Liquid Crystal Display displaying data and settings Position 14 Communication window For use of external communication devices Position 15 Sealing points The meter has 2 sealable covers with 2 sealable points on each where thread seals can be used to seal the meter covers all meter connections and the 2 buttons 2 3 METER TYPES As mentioned above the DELTAplus meter product family is divided into two groups e Direct connected meters for current
44. is data error or no data available the standard M bus status coding values will be sent out 18 hex or 15 hex The register values have same data and value information bytes dif dife s vif vife s as for the momentary register vales but with stored number 1 to indicate that it is stored historical data Below are a number of commented practical examples of a number of load profile readouts where data sent to and read from the meter is shown All data is in hexadecimal format Comments are preceded with a semicolon Readout of 1 day of active energy load profile register values System sends read request command for active energy register values 68 68 73 FE 51 02 EC FF F9 10 C5 04 81 16 Date 5 th of april year 06 Meter sends out acknowledge E5 System sends out request UD2 10 7B FE 79 16 Meter sends out data telegram 68 A1 A1 68 08 00 72 44 47 24 00 42 04 02 02 16 00 00 00 Data header 44 ED 6B 00 01 C5 04 Date and time for first register value in telegram end of 1 st interval 01 FD 25 3C Interval length 60 minutes 4E 04 81 14 00 00 00 00 Register value end of 1 st interval 14 81 kWh status VIFE not sent status 0 04 98 15 00 00 00 00 Register value 15 98 kWh 04 15 17 00 00 00 00 04 13 18 00 00 00 00 04 64 18 00 00 00 00 04 78 19 00 00 00 00 04 59 20 00 00 00 00 04 71 21 00 00 00 00 E 84 FF FE 04 80 22 00 00 00 00 Register value 22 80 kWh manufacturer specific stat
45. is pending It will also happen if a particular tariff haven t been active in a measurement period Page 115 of 137 DELTAplus meter User s Manual Rev If the data item read is normal with no specific status associated with it no status VIFE will be sent out or will be sent out If the status is data error or no data available the standard M bus status coding values will be sent out 18 hex or 15 hex Below are a number of commented practical examples of a maximum demand readouts where data sent to and read from the meter is shown All data is in hexadecimal format Comments are preceded with a semicolon System sends read request command for maximum demand 68 0A 0A 68 73 FE 51 02 EC FF F9 18 C1 07 88 16 Meter sends out acknowledge E5 System sends out request UD2 10 7B FE 79 16 Meter sends out data telegram 68 E8 E8 68 08 00 72 44 47 24 00 42 04 02 02 04 00 00 00 Data header 01 FD 25 OF Interval length 15 minutes 94 10 29 60 57 2A 00 Current maximum demand storage number 0 for active power tariff 1 VIF 29 gt data in W with 2 decimals Data 2A5760hex 27748 80 W 8E 00 ED 6B 00 15 00 01 07 06 Date time stamp for maximum given above 1 st of july 2006 00 15 00 hour minute second 94 20 29 00 00 00 00 Current maximum demand storage number 0 for active power tariff 2 29 gt data in with 2 decimals Data 0 8E 00 ED 6B 00 00 00 00 00 00 Date time stamp for maximum given above is 0
46. outputs is depicted below and consists of an ideal relay and a series resistor of typically 20 Q Fig 2 17 Pulse output equivalent schematic diagram 2 11 1 PULSE FREQUENCY AND PULSE LENGTH The pulse frequency is programmable marked on the nameplate with the pulse frequency selected from a list using the buttons The pulse length is fixed and is normally set to 100 ms Regarding the choice of pulse frequency it should be noted that there is a risk that the pulses may go into each other if the power is too high In this case the meter may send out a new pulse closes the relay before the previous pulse has been terminated relay opened and the pulse will be missed The worst case scenario is that the relay can be closed all the time To avoid this problem a calculation should be made to work out the maximum pulse frequency allowed at a particular site based upon an estimated maximum power and the meter pulse output data The formula to use when doing this calculation is Page 35 of 137 DELTAplus meter User s Manual Rev Max pulse frequency 1000 3600 U 1 n Ppause Pwidth where U and is the estimated maximum element voltage in volts and current in amperes n the number of elements 1 3 Pwidth and Ppause is the pulse width and the required pulse pause in seconds A reasonable minimum pulse pause is 0 03 30 ms which conforms to the SO standard Note U and have to be the primary values i
47. tariff inputs consist of 2 inputs numbered 15 Ti and 16 and 3 rd common input numbered 13 see below For 2 tariff meters is used For 4 tariff meters both and are used C T T IN1 IN2 Fig 2 16 Tariff input connection diagram For more data regarding the tariff inputs see section 2 9 and section 3 3 1 technical data for high voltage inputs 2 10 2 INDICATION OF ACTIVE TARIFF The active tariff is reflected on the LCD by blinking with one of the 4 segments T1 T2 T3 and T4 T1 blinks if tariff 1 is active T2 if tariff 2 is active etc The active tariff segment will always blink except when the total active or reactive energy is displayed where all Tx segments are off 2 10 3 INPUT CODING The normal coding of the inputs is binary as described below Reservations should be made however for special meters where different coding is required Meter with 4 tariffs The inputs have the following input voltage active tariff table Off off gt Tariff 1 active T1 blinks on the LCD Ak 1 PADDED Page 34 of 137 DELTAplus meter User s Manual Rev on off gt Tariff 2 active T2 blinks on the LCD Off on gt Tariff 3 active T3 blinks on the LCD gt Tariff 4 active T4 blinks on the LCD Meter with 2 tariffs Tini T ino Off off gt Tariff 1 active Tini Tin2 on off gt Tariff 2 acti
48. the same in all phases giving the same current amplitude and phase angle in all phases It should be mentioned that even if the load is perfectly balanced the accuracy will be decreased if the incoming voltages are not perfectly balanced same voltage amplitude on all phases and exact 120 degrees phase angle between the phases 5 1 ACTIVE AND REACTIVE POWER Active power is needed to perform work which is the purpose of delivering electricity To understand the need for the utility to measure the active energy is easy as it needs this information to bill its customer correctly Usually the more energy the customer consumes the higher the accuracy of the meter needs to be Normally 4 accuracy classes are used 2 small consumers e g households 1 0 5 and 0 2 meters with defined power levels for each class Also from a customer point of view it is easy to understand the need to measure the active energy as it can give him information about how to decrease the consumption and reduce the bill It can also be used to distribute the internal costs within for example in industry building complexes such as office complexes shopping centers airports marinas camping places A further use is for distributing costs when centralized utility measuring of many households is used block of flats many houses with only one utility billing point etc Sometimes there is also a need to measure the reactive energy Consumer equipment often introduces
49. to the meter and to 0 in the other direction The frame count bit valid FCV is set to 1 by the master to indicate that the frame count bit FCB is used When the FCV is set to O the meter ignores the FCB e The FCB is used to indicate successful transmission procedures A master shall toggle the bit after a successful reception of a reply from the meter If the expected reply is missing or the reception of it is faulty the master resends the same telegram with the same FCB The meter answers to REQ UD2 request with toggled FCB and a set FCV with a RSP_UD containing the next telegram of a multi telegram answer If the FCB is not toggled it will repeat the last telegram The actual values will be updated in a repeated telegram On receipt of a SND NKE the meter clears the FCB The meter uses the same FCB for primary addressing secondary addressing and point to point communication The bits 0 to 3 FO F1 F2 and of the control field are the function code of the message Name C field binary C field hex Telegram Description SND NKE 0100 0000 40 Short Frame Initialization of Meter SND UD 0181 0011 53 73 Long Frame Send User Data to Meter REQ UD2 01 1 1011 5B 7B Short Frame Request for Class 2 Data UD 0000 1000 08 Long Frame Data Transfer from Meter to Master after Request Function Codes Address Field A field The address field is used to address the recipient in the c
50. with 1 decimal 30 1 02 DIF size 2 byte integer 31 1 FF VIF next byte is manufacturer specific 32 1 ED VIFE current harmonics 33 1 FF VIF next byte is manufacturer specific 34 1 8x VIFE phase x 35 1 FF VIF next byte is manufacturer specific 36 1 F8 Extension of manufacturer specific vife s next vife s used for numbering 37 1 02 Harmonic number 38 39 2 XXXX 2 nd harmonic in percent with 1 decimal 40 1 02 DIF size 2 byte integer 41 1 FF VIF next byte is manufacturer specific 42 1 ED VIFE current harmonics 43 1 FF VIF next byte is manufacturer specific 44 1 8x VIFE phase x 45 1 FF VIF next byte is manufacturer specific 46 1 F8 Extension of manufacturer specific vife s next vife s used for numbering 47 1 03 Harmonic number 48 49 2 XXXX 3 rd harmonic in percent with 1 decimal 50 1 02 DIF size 2 byte integer 51 1 FF VIF next byte is manufacturer specific 52 1 ED VIFE current harmonics 53 1 FF VIF next byte is manufacturer specific 54 1 8x VIFE phase x 55 1 FF VIF next byte is manufacturer specific 56 1 F8 Extension of manufacturer specific vife s next vife s used for numbering 57 1 04 Harmonic number 58 59 2 XXXX 4 th harmonic in percent with 1 decimal 4 127 of 137 DELTAplus meter User s Manual Rev Harmonic data continued Byte No Size in bytes
51. 0 00 00 00 00 00 gt no maximum have been generated for this quantity 94 30 29 00 00 00 00 8E 00 ED 6B 00 00 00 00 00 00 94 80 10 29 00 00 00 00 8E 00 ED 6B 00 00 00 00 00 00 94 90 40 29 60 5E 0A 00 8E 00 ED 6B 00 15 00 01 07 06 94 AO 40 29 00 00 00 00 8E 00 ED 6B 00 00 00 00 00 00 94 BO 40 29 00 00 00 00 8E 00 ED 6B 00 00 00 00 00 00 94 80 50 29 00 00 00 00 8E 00 ED 6B 00 00 00 00 00 00 94 40 FD 61 00 00 00 00 8E 00 ED 6B 00 00 00 00 00 00 94 80 40 FD 61 00 00 00 00 8E 00 ED 6B 00 00 00 00 00 00 8E 00 ED EB FF 70 00 00 00 00 00 00 Date time stamp for end of measurement period will always be 00 00 00 00 00 00 for the currently pending period 1F Did 1F gt More data exists 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 Pad bytes 14 16 Checksum and stop byte System sends out request UD2 10 5B FE 59 16 Meter sends out data telegram 68 E8 E8 68 08 00 72 44 47 24 00 42 04 02 02 05 00 00 00 Data header 01 FD 25 Interval length 15 minutes D4 10 29 40 90 02 00 Maximum demand storage number 1 for active power tariff 1 29 gt data in with 2 decimals Data 29040hex 1680 00 W CE 00 ED 6B 26 29 01 03 06 06 Date time stamp for maximum given above 3 rd of june 2006 01 29 26 hour minute second 116 of 137 DELTAplus meter User s Manual Rev D4 20 29 00 00 00 00 Maximum demand storage number 1 for active power tariff 2 VIF 29 gt data in W with 2 decimals Data
52. 00 80 40 FD 61 52 23 00 00 00 00 CE 80 40 FD 61 52 23 00 00 00 00 80 40 61 52 23 00 00 00 00 80 40 61 52 23 00 00 00 00 80 40 61 52 23 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 62 16 Sending request UD2 10 5b fe 59 16 Reading response 68 C5 C5 68 08 00 72 42 10 00 00 42 04 02 02 16 20 00 00 44 ED 24 00 00 AC OC 01 FD 25 3C CE 80 40 FD 61 52 23 00 00 00 00 CE 80 40 FD 61 52 23 00 00 00 00 CE 80 40 FD 61 52 23 00 00 00 00 CE 80 40 FD 61 52 23 00 00 00 00 CE 80 40 FD 61 52 23 00 00 00 00 CE 80 40 FD 61 52 23 00 00 00 00 CE 80 40 FD 61 52 23 00 00 00 00 CE 80 40 FD 61 52 23 00 00 00 00 CE 80 40 FD 61 52 23 00 00 00 00 CE 80 40 FD 61 52 23 00 00 00 00 CE 80 40 FD 61 52 23 00 00 00 00 CE 80 40 FD 61 52 23 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 0000 00 00 00 00 00 00 00 00 00 63 16 Readout of 1 day of input 2 load profile interval values System sends read request command for input 2 interval values 68 0A 0A 68 53 FE 51 02 EC FF F9 17 AC OC 57 16 Reading acknowledge e5 113 of 137 DELTAplus meter User s Manual Rev Sending request UD2 10 7B E 79 16 Reading response
53. 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 OF Dif OF gt No more events exist 00 00 00 00 00 00 AD 16 Readout of 1 telegrams of event log with offset 0 System sends event log read request command date time 13 3 06 15 39 55 offset 0 68 12 12 68 73 FE 51 8E 80 80 80 00 ED FF F9 55 39 15 13 03 06 8E 16 Meter sends out acknowledge E5 System sends out request UD2 FE 79 16 10 7B Meter sends out data telegram 68 7E 7E 68 08 00 72 42 10 00 00 42 04 02 02 27 00 00 OO Data header 01 FF 6F 01 Total power outage OE ED 39 44 38 15 13 03 06 Time date 44 38 15 13 03 06 sec min hour day month year 04 20 52 01 00 00 Duration 338 seconds 01 FF 6F OF Abnormal negative power OE ED 39 28 44 15 13 03 06 Time date 28 44 15 13 03 06 sec min hour day month year 04 20 23 00 00 00 FF 6F 01 Total power outage OE ED 39 12 45 15 13 03 06 4 PADDED Page 125 of 137 DELTAplus meter User s Manual Rev 04 20 5B 00 00 00 01 FF 6F 01 Total power outage ED 39 24 19 09 14 03 06 04 20 FE 00 00 00 01 FF EF 15 00 Status VIFE 15 gt No data available OE ED B9 15 00 00 00 00 00 00 04 AO 15 00 00 00 00 OF Dif OF gt No more events exist 00 00 00 00 00 00 00 00 00 00 00 00 04 16 6 1 4 3 5 Read request and readout of current harmonics Read request of current harmonics
54. 00 00 00 00 00 00 00 00 Pad bytes 62 16 Checksum and stop byte System sends out request UD2 10 5B FE 59 16 Meter sends out data telegram 68 9C 9C 68 08 00 72 44 47 24 00 42 04 02 02 0A 00 00 00 01 ED 6B 00 00 00 01 06 06 Date time stamp for monthly values here 01 06 06 00 00 00 day month year sec min hour 01 04 17 05 00 00 00 00 11 04 55 01 00 00 00 00 8E 21 04 27 02 00 00 00 00 8E 31 04 31 00 00 00 00 00 8E 81 10 04 04 01 00 00 00 00 8E 81 40 04 26 01 00 00 00 00 8E 91 40 04 38 00 00 00 00 00 8E A1 40 04 55 00 00 00 00 00 8E B1 40 04 07 00 00 00 00 00 8E 81 50 04 25 00 00 00 00 00 41 FD 61 00 00 00 00 00 00 8E 81 40 FD 61 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 Page 119 of 137 DELTAplus meter User s Manual Rev E9 16 6 1 4 3 4 Read request and readout of event log data Read request of event log is done by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 12 L field calculated from C field to last user data 3 1 12 L field repeated 4 1 68 Start character 5 1 53 73 C field SND_UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 8E or CE DIF size 6 byte bcd storage number bit 0 is 0 or 1 9 1 8x or Cx DIFE storage number bits 1 4 unit bit 6 is O or 1 10 1 8x DIFE storage numbe
55. 00 00 00000000 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 BA 16 Readout of 1 day of active energy load profile interval values System sends read request command for active energy interval values 68 OA 0A 68 73 FE 51 02 EC FF F9 11 C5 04 82 16 Date 5 th of april year 06 Meter sends out acknowledge E5 System sends out request UD2 10 7B FE 79 16 Meter sends out data telegram 68 9E 9E 68 08 00 72 44 47 24 00 42 04 02 02 20 00 00 00 Data header 44 ED 00 00 C5 04 Date and time 5 th of april year 06 00 00 for start of 1 st interval and of register value FD 25 3C Interval length 60 minutes 04 64 13 00 00 00 00 Register value at start of 1 interval in telegram 13 64 kWh 83 27 92 04 00 00 tsstinterval value Consumption 1 170 kWh 492 hex 83 27 91 04 00 00 2 nd interval value Consumption 1 169 kWh 491 hex 27 90 04 00 00 83 27 D6 03 00 00 83 27 FD 01 00 00 83 27 77 04 00 00 83 27 27 03 00 00 83 27 61 04 00 00 83 A7 FF FE 04 04 00 00 91 interval value Consumption 1 086 kWh 43E hex manufacturer specific status 04 total power outage occured during interval KBD ADR uS uS B QA AAR A AB Ww 44 83 27 9E 04 00 00 44 83 A7 FF FE 01 A4 04 00 00 44 83 27 C1 04 00 00 1 Dif 1F gt Exist more load profile data 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 Pad bytes 00 00 00
56. 1 status if not OK 2 always 12 1 CS checksum calculated from field to last data 13 1 16 Stop character This command is not affected by the write protection level set Page 97 of 137 DELTAplus meter User s Manual Rev 6 1 4 2 9 Reset of stored state for input 1 Reset of stored state for input 1 is done by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 08 L field calculated from C field to last user data 3 1 08 L field repeated 4 1 68 Start character 5 1 53 73 C field SND_UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 DIF size data storage number 1 9 1 40 DIFE unit 1 10 1 FD VIF extension of VIF codes 11 1 9B VIFE digital input 12 1 07 VIFE clear 13 1 XX CS checksum calculated from C field to last data 14 1 16 Stop character This command is not affected by the write protection level set 6 1 4 2 10 Reset of stored state for input 2 Reset of stored state for input 2 is done by sending the following command all values are hexadecimal Byte Size in bytes Value Description 1 1 68 Start character 2 1 09 L field calculated from C field to last user data 3 1 09 L field repeated 4 1 68 Start character 5 1 53 73 C field SND UD 6 1 XX A field address 7 1 51 Cl field data send
57. 1 Total active power d N i Reactive power for each element 1 Total reactive power i 1 Total active and reactive consumption 1 Total apparent power i Date and time 1 A Voltage and current for each element transformer ratio power factor 1 1 1 1 1 1 1 1 Voltage transformer ratio LLL Current transformer ratio 1 1 1 1 1 1 1 1 1 LSc Frequency LSc counter 1 counter 2 Current harmonics Input status 1 2 stored status 1 2 Pulse output frequency Primary address Baudrate Communication status LED reactive 1 1 1 1 1 1 1 1 LSc Active quadrant 1 1 1 1 1 1 1 1 Write protection level 1 5 15 Set CT ratio Set VT ratio Set Pulse Set M bus Set M bus Set Date Set Time Set Write frequency baud rate address access level S Set button press E Sc short press Scroll button VT CT connected only LSc Long Scroll Scroll button pressed 2 sec or more optional When LSc is used in a set operation it acts like an escape that is s it goes out of the active set operation and no change is performed Items with italic font are optional Fig 2 12 Display system 2 71 NORMAL MODE Normal Mode is the normal display condition where the most important quantities normally the energies which are used for billing are di
58. 1 16 Stop character Note that the maximum total transformer ratio CT VT must be less than 1 000 000 This command is not accepted by a direct connected meter This command is not affected by the write protection level set 6 1 4 2 6 Set voltage transformer VT ratio The voltage transformer ratio VT is set by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 08 L field calculated from C field to last user data 3 1 08 L field repeated 4 1 68 Start character 5 1 53 73 C field SND UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 0 DIF size 4 digit BCD 9 1 FF VIF next byte is manufacturer specific 10 1 69 VIFE VT ratio 11 12 2 XX XX New VT ratio 13 1 XX CS checksum calculated from C field to last data 14 1 16 Stop character Note that the maximum total transformer ratio CT VT must be less than 1 000 000 This command is not accepted by a direct connected meter This command is not affected by the write protection level set Page 96 of 137 DELTAplus meter User s Manual Rev 6 1 4 2 7 Set transformer ratio CT VT This command sets the CT ratio and is only implemented for backward compatibility If using the command the maximum ratio sent shall be less than 10 000 Byte No Size in bytes Value Description 1
59. 1 3 FLUSH MOUNTED To flush mount the meter a flush mount kit is used see fig 4 3 below Fig 4 3 Flush mount kit Page 51 of 137 DELTAplus meter User s Manual Rev 42 WIRING DIAGRAMS Below is described how to connect the different types of DELTAplus meters to your electricity network The terminal numbers given in the pictures are also marked in the plastic on the terimal block of the meter The DELTAplus meter must always be protected by fuses on the incoming side In order to allow the maintenance of the transformer rated DELTAplus meter it is recommended that there should be a short circuiting terminal block installed near the DELTAplus meter In transformer rated meters the DELTAplus meter voltage supply must be protected by a maximum 10 fuse 4 21 DIRECT CONNECTED METERS Single phase direct connected meter 2 element direct connected meter 3 element direct connected meter Fig 4 4 Wiring diagrams for direct connected meters PADDED Page 52 of 137 DELTAplus meter User s Manual Rev 4 2 2 TRANSFORMER RATED METERS WITHOUT VOLTAGE TRANSFORMER 3 element transformer rated meter 23 4 5 6 7 8 11 12 L3 Fig 4 5 Wiring diagrams for transformer rated meters without voltage transformers Page 53 of 137 DELTAplus meter User s Manual Rev 4 2 3 TRANSFORMER RATED METER WITH
60. 16 Meter sends out data telegram 68 9C 9C 68 08 00 72 44 47 24 00 42 04 02 02 09 00 00 00 Data header date time stamp and the monthly values have storage number 1 that is it is the 1 51 most recent in time set of monthly values CE 00 ED 6B 00 00 00 01 07 06 Date time stamp for monthly values here 01 07 06 00 00 00 day month year sec min hour CE 00 04 35 08 00 00 00 00 Monthly value for total active energy here 8 35 KWh CE 10 04 62 02 00 00 00 00 Monthly value for tariff 1 active energy here 2 62 kWh CE 20 04 27 02 00 00 00 00 Monthly value for tariff 2 active energy here 2 27 kWh CE 30 04 79 00 00 00 00 00 Monthly value for tariff 3 active energy here 0 79 kWh CE 80 10 04 65 02 00 00 00 00 Monthly value for tariff 4 active energy here 2 65 KWh CE 80 40 04 04 02 00 00 00 00 Monthly value for total reactive energy here 2 04 kvarh CE 90 40 04 64 00 00 00 00 00 Monthly value for tariff 1 reactive energy here 0 64 kWh CE 40 04 55 00 00 00 00 00 Monthly value for tariff 2 reactive energy here 0 55 kWh CE 40 04 19 00 00 00 00 00 Monthly value for tariff 3 reactive energy here 0 19 kWh CE 80 50 04 65 00 00 00 00 00 Monthly value for tariff 4 reactive energy here 0 65 kWh CE 40 FD 61 00 00 00 00 00 00 Monthly value for input 1 counter here 0 pulses CE 80 40 FD 61 00 00 00 00 00 00 Monthly value for input 2 counter here 0 pulses Dif 1F gt more monthly values exist 00 00 00 00 00
61. 2 1 ED VIFE current harmonics 103 1 FF VIF next byte is manufacturer specific 104 1 8x VIFE phase x 105 1 FF VIF next byte is manufacturer specific 106 1 F8 Extension of manufacturer specific vife s next vife s used for numbering 107 1 05 Harmonic number 108 109 2 XXXX 5 th harmonic in percent with 1 decimal 110 1 1F DIF more records will follow in next telegram 111 119 9 000000000000000 PAD bytes 000 120 1 XX CS checksum calculated from C field to last data 121 1 16 Stop character EP ED 123 of 137 DELTAplus meter User s Manual Rev Below are a number of commented practical examples of a number of event log readouts where data sent to and read from the meter is shown All data is in hexadecimal format Comments after sent or received bytes are preceded with a semicolon Readout of 4 telegrams of event log with offset 1 System sends event log read request command date time 14 3 06 09 51 40 offset 1 68 12 12 68 73 FE 51 CE CO 80 80 00 ED FF F9 1A 40 51 09 14 03 06 06 16 Meter sends out acknowledge E5 System sends out request UD2 10 7B FE 79 16 Meter sends out data telegram 68 7E 7E 68 08 00 72 42 10 00 00 42 04 02 02 05 00 00 00 Data header 01 FF 6F 01 Total power outage OE ED 39 24 19 09 14 03 06 Time date 39 24 09 14 03 06 sec min hour day month year 04 20 FE 00 00 00 Duration 254 seconds 01 F
62. 2 Meter dimensions Page 45 of 137 DELTAplus meter User s Manual Rev 3 TECHNICAL DATA 3 1 DIRECT CONNECTED METER 3 1 1 VOLTAGE CURRENT INPUTS Nominal voltage 3 x 57 288 100 500 V 4 wire 3 element 3 x 100 500 V 3 wire 2 element 1 x 57 288 V Single phase Voltage range 20 to 15 of nominal voltage Power dissipation voltage circuits Less than 1 VA 1 W per phase Power dissipation Less than I k VA on all inputs where l is current in amperes and k is less than 0 0005 typically 0 0003 Base current 5 A Reference current 5 A Maximum current 80 A Transitional current 0 5 A Minimum current 0 25 A Starting current 20 mA Terminal wire area 1 0 25 Recommended tightening torque 2 5 Nm 3 1 2 GENERAL DATA Frequency 50 60 Hz 5 Accuracy According to IEC 62053 21 Cl 2 or Cl 1 for active energy According to IEC 62053 23 CI 2 for reactive energy Display of energy LCD with 7 digits height 7 mm 3 1 3 MECHANICAL DATA AND TESTS Material Polycarbonate in transparent front glass bottom case upper case and terminal cover Glass reinforced polycarbonate in terminal block Protection class 11 Glow wire test according to IEC 695 2 1 Dust and water protection acc to IEC 60529 protection class IP51 mounted in protective enclosure 1 20 on terminal block without protective enclosure Weight 0 338 kg 3 1 4 ENVIRONMENT DATA AND TESTS Operating temperature range 40 to 55 C S
63. 6 1 3 2 1 Selection and Secondary Addressing sse nennen nennen 79 6 1 4 TELEGRAMS alse need 80 AA EP ED PADDED Page 4 of 137 DELTAplus meter User s Manual Rev TABLE OF CONTENTS 6 1 4 1 Examples of telegram 1 4 82 0 1 4 2 Sending data tothe meter er b eere ertt tp 87 ELAI Set tanith iidem dou ERI EDD nt 87 6 1 4 2 2 Set primary EEREEEA 87 6 1 4 2 3 Change Daud 87 6 1424 Reset power fail Counter aee anni eder dri iiie 87 6 1 4 2 5 Set current transformer CT enne enne nennen enne enne 87 6 1 4 2 6 Set voltage transformer VT 87 6 1 4 2 7 Set transformer tatio CT VT eisini 87 6 1 4 2 8 Select status aDformation EC rte ese iret 87 6 1 4 2 9 Reset of stored state for input 1 87 6 1 4 2 10 Reset of stored state for input 2 87 6 1 4 211 Resetotinput counter 87 6 1 4 2 12 Reset of input counter2 esae oec tre 87 6 1 4 2 13 Setoutput CE 87 0 1 4 2 14 Setoutput 2 ere ee ert edere SL
64. Communication adapter for GSM GPRS DIN rail for wall mounting LONG cover for wall mounting External counter for panel mounting Front mounting kit for panel mounting Time switch clock for tariff control 99 837 090 99 837 091 99 837 092 99 837 093 99 837 103 99 837 104 09 811 02 09 811 81 09 811 04 09 811 84 19 102 30 Page 136 of 137 DELTAplus meter User s Manual Rev 8 SERVICE AND MAINTENANCE 8 1 RECALIBRATION It should not be necessary to recalibrate the DELTAplus meter during its lifetime as it is an electronic meter with no moving parts with electronics and voltage and current sensors that do not naturally degrade or change with time under specified environmental conditions If a degradation in the accuracy is observed the meter has probably been partly damaged for example due to lightning strike or extreme environmental conditions etc and should be sent for repair or exchanged 8 2 CLEANING If the meter is dirty and needs to be cleaned use lightly moistened tissue with a water based mild detergent Make sure no liquid goes into the meter as this could damage the meter Page 137 of 137
65. Current consumption at space state Communication speed Electrical characteristics of the M Bus interface Page 71 of 137 DELTAplus meter User s Manual Rev 6 13 PROTOCOL DESCRIPTION The M Bus protocol is based on the international standard IEC 60870 but it doesn t use all of the specified functions When there is no communication on the bus it is in Mark state Each communicated byte consists of eleven bits The bits are one start bit space eight data bits one parity bit even and one stop bit mark The least significant bit is transmitted first Calling direction master to meter 11 20 IMark Fig 6 1 Transmission of a Character in Calling and Replying Direction 6 1 3 1 Telegram formats The telegram formats are structured according to format class FT1 2 The FT1 2 format fulfils the data integrity class I2 including a Hamming Distance of four Three telegram formats are used The start character identifies the different telegram formats Single Character Short Frame Long Frame E5h Start 10h Start 68h C field L field A field L field Check Sum Start 68h Stop 16h C field A field Cl field User Data 0 252 byte Check Sum Stop 16h Telegram Formats e Single Character The Single Character format consists of a single character E5h and is used to acknowledge received telegrams Short Frame The Short Frame forma
66. DIF size 8 bit integer 142 1 80 DIFE 143 1 40 DIFE Unit 2 144 1 FD VIF extension of VIF codes 145 1 1B VIFE digital input 146 1 XX Input 2 current state 147 1 C1 DIF size 8 bit integer storage number 1 148 1 40 DIFE Unit 1 149 1 FD VIF extension of VIF codes 150 1 1B VIFE digital input 151 1 XX Input 1 stored state 1 if current state has been 1 152 1 C1 DIF size 8 bit integer storage number 1 153 1 80 DIFE 154 1 40 DIFE Unit 2 155 1 FD VIF extension of VIF codes 156 1 1B VIFE digital input 157 1 XX Input 2 stored state 1 if current state has been 1 158 1 8E DIF size 12 digit BCD 159 1 40 DIFE Unit 1 160 1 FD VIF extension of VIF codes 161 1 61 VIFE cumulating counter 162 167 6 Counter 1 input 1 168 1 8E DIF size 12 digit BCD 169 1 80 DIFE 170 1 40 DIFE Unit 2 171 1 FD VIF extension of VIF codes 172 1 61 VIFE cumulating counter 173 178 6 XXXXXXXXXXXX Counter 2 input 2 179 1 81 DIF size 8 bit integer 180 1 40 DIFE Unit 1 181 1 FD VIF extension of VIF codes 182 1 1A VIFE digital output 183 1 XX Output 1 current state EP ED 90 of 137 DELTAplus meter User s Manual Rev Example of the 3 telegram continued all values are hexadecimal Byte No Size in bytes Value Description 184 1 81 DIF size 8 bit integer 185 1 80 DIFE 186 1 40 DIFE Unit 2 187 1 FD VIF extension of VIF cod
67. E for units V with resolution 0 1V 132 1 FF VIFE next byte is manufacturer specific 133 1 03 VIFE L3 134 135 2 XXXX Voltage L3 N 4 86 of 137 DELTAplus meter User s Manual Rev Example of the 2m telegram continued all values are hexadecimal Byte Size in bytes Value Description 136 1 0 DIF size 4 digit BCD 137 1 FD VIF extension of VIF codes 138 1 for units V with resolution 0 1V 139 1 FF VIFE next byte is manufacturer specific 140 1 05 VIFE L1 L2 141 142 2 XXXX Voltage L1 L2 143 1 0A DIF size 4 digit BCD 144 1 FD VIF extension of VIF codes 145 1 C8 VIFE for units V with resolution 0 1V 146 1 FF VIFE next byte is manufacturer specific 147 1 06 VIFE L2 L3 148 149 2 XXXX Voltage L3 L2 150 1 0A DIF size 4 digit BCD 151 1 FD VIF extension of VIF codes 152 1 DA VIFE for units A with resolution 0 01A 153 1 FF VIFE next byte is manufacturer specific 154 1 01 VIFE L1 155 156 2 XXXX Current L1 157 1 0A DIF size 4 digit BCD 158 1 FD VIF extension of VIF codes 159 1 DA VIFE for units A with resolution 0 01A 160 1 FF VIFE next byte is manufacturer specific 161 1 02 VIFE L2 162 163 2 XXXX Current L2 164 1 0A DIF size 4 digit BCD 165 1 FD VIF extension of VIF codes 166 1 DA VIFE for units A with resolution 0 01A 167 1 FF VIFE next byte is manufacturer specific 168 1 03 VIFE L3 169 170 2 XXXX Current L3 171 1 0A DIF
68. E100 nnnn 1 9 Volts E101 nnnn 10nnnn 12 A E110 0001 Cumulating Counter E001 0110 Password Table FD 76 of 137 DELTAplus meter User s Manual Rev Codes for Value Information Field Extension VIFE The following values for VIFE s are defined for an enhancement of VIF s other than FDh and FBh VIFE Code Description E010 0111 per measurement interval E010 0111 per measurement interval E010 0111 per measurement interval E011 1001 Start date time of E110 1f1b Date time of b 0 end of b 1 begin of is not used in meter always 0 1144 1444 ext is manufacturer specific Manufacturer specific VIFE Codes VIFE Code Description E000 0000 Total E000 0001 L1 E000 0010 L2 E000 0011 L3 E000 0101 11 12 000 0110 L3 L2 E001 0000 Pulse frequency E001 0010 Transformer ratio CT VT E001 0011 Tariff E001 0100 Installation check E001 0101 Status of values E001 0110 Current quadrant E001 1000 Power fail counter E100 Phase angle voltage degrees 10 3 E100 1nnn Phase angle current degrees 10 3 E101 Onnn Phase angle power degrees 10 3j E101 1nnn Frequency Hz 10 7 3 E110 Onnn Power factor 10 773 E110 1000 Current Transformer ratio CT ratio E110 1001 Voltage Transformer ratio VT ratio E110 1010 Change communication write access level E110 1011 Cha
69. F 6F 01 Total power outage OE ED 39 12 45 15 13 03 06 Time date 12 45 15 13 03 06 sec min hour day month year 04 20 5B 00 00 00 Duration 91 seconds 01 FF 6F OF Abnormal negative power OE ED 39 28 44 15 13 03 06 04 20 23 00 00 00 01 FF 6F 01 Total power outage OE ED 39 44 38 15 13 03 06 04 20 52 01 00 00 01 FF 6F OD Undervoltage on phase 3 level 2 OE ED 39 36 25 15 13 03 06 04 20 3E 00 00 00 Dif 1F gt More events exist 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 Pad bytes 0 16 Checksum and stopbyte System sends out request UD2 10 5B FE 59 16 Meter sends out data telegram 68 7E 7E 68 08 00 72 42 10 00 00 42 04 02 02 06 00 00 OO Data header 01 FF 6F OC Undervoltage on phase 2 level 2 OE ED 39 36 25 15 13 03 06 Time date 36 25 15 13 03 06 sec min hour day month year 04 20 3E 00 00 00 Duration 62 seconds 01 FF 6F OB Undervoltage on phase 1 level 2 OE ED 39 36 25 15 13 03 06 04 20 3E 00 00 00 01 FF 6F 04 Power outage on phase 3 OE ED 39 36 25 15 13 03 06 04 20 3E 00 00 00 01 FF 6F 03 Power outage on phase 2 OE ED 39 36 25 15 13 03 06 04 20 3E 00 00 00 01 FF 6F 02 Power outage on phase 1 OE ED 39 36 25 15 13 03 06 04 20 3E 00 00 00 gt More events exist 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 30 16 System sends out request UD2 10 7B FE 79 16 124 137 DELTAplu
70. F size 16 bit integer 66 1 FF VIF next byte is manufacturer specific 67 1 D2 VIFE phase angle power with resolution 0 1 68 1 FF VIFE next byte is manufacturer specific 69 1 03 VIFE L3 70 71 2 XXXX Phase angle power L3 72 1 02 DIF size 16 bit integer 73 1 FF VIF next byte is manufacturer specific 74 1 C2 VIFE phase angle voltage with resolution 0 1 75 1 FF VIFE next byte is manufacturer specific 76 1 01 VIFE L1 71 78 2 XXXX Phase angle voltage L1 79 1 02 DIF size 16 bit integer 80 1 FF VIF next byte is manufacturer specific 81 1 C2 VIFE phase angle voltage with resolution 0 1 82 1 FF VIFE next byte is manufacturer specific 83 1 02 VIFE L2 84 85 2 XXXX Phase angle voltage L2 86 1 02 DIF size 16 bit integer 87 1 FF VIF next byte is manufacturer specific 88 1 C2 VIFE phase angle voltage with resolution 0 1 89 1 FF VIFE next byte is manufacturer specific 90 1 03 VIFE L3 91 92 2 XXXX Phase angle voltage L3 93 1 02 DIF size 16 bit integer 94 1 FF VIF next byte is manufacturer specific 95 1 CA VIFE phase angle current with resolution 0 1 96 1 FF VIFE next byte is manufacturer specific 97 1 01 VIFE L1 98 99 2 XXXX Phase angle current L1 100 1 02 DIF size 16 bit integer 101 1 FF VIF next byte is manufacturer specific 102 1 CA VIFE phase angle current with resolution 0 1 103 1 FF VIFE next byte is manufacturer specific 104 1 02 VIFE L2 105 106 2 XXXX Phase angle current L2 107 1 02 DIF size 16 bit integer 108 1 FF VIF next b
71. IF size 12 digit BCD storage number bit 0 40 1 10 DIFE tariff 1 storage number bit 1 4 41 1 04 VIF for units kWh with resolution 0 01kWh 42 47 6 XXXXXXXXXXXX Active energy tariff 1 48 1 CE DIF size 12 digit BCD storage number bit 0 49 1 20 DIFE tariff 2 storage number bit 1 4 50 1 04 VIF for units kWh with resolution 0 01kWh 51 56 6 XXXXXXXXXXXX Active energy tariff 2 57 1 CE DIF size 12 digit BCD storage number bit 0 58 1 30 DIFE tariff 3 storage number bit 1 4 59 1 04 VIF for units KWh with resolution 0 01kWh 60 65 6 XXXXXXXXXXXX Active energy tariff 3 66 1 CE DIF size 12 digit BCD storage number bit 0 67 1 80 DIFE tariff bits 0 1 storage number bit 1 4 68 1 10 DIFE tariff bits 2 3 tariff 4 69 1 04 VIF for units kWh with resolution 0 01kWh 70 75 6 XXXXXXXXXXXX Active energy tariff 4 76 1 CE DIF size 12 digit BCD storage number bit 0 77 1 80 DIFE storage number bit 1 4 unit bit 0 78 1 40 DIFE unit bit 1 79 1 04 VIF for units kvarh with resolution 0 01kvarh 80 85 6 XXXXXXXXXXXX Reactive energy total 86 1 CE DIF size 12 digit BCD storage number bit 0 87 1 90 DIFE tariff 1 storage number bit 1 4 unit bit 0 88 1 40 DIFE unit bit 1 89 1 04 VIF for units kvarh with resolution 0 01kvarh 90 95 6 XXXXXXXXXXXX Reactive energy tariff 1 4 PADDED Page 92 of 137 DELTAplus meter User s Manual Rev Example of the 4 telegram continued all values are hexadecimal
72. Input 2 number of counts per interval 13 14 2 XXXXXXXXXXXX Time date sec min hour day month year 15 1 XX CS checksum calculated from C field to last data 16 1 16 Stop character If load profile data for the specified time date is stored in the meter it will send out the dataframe containing the data for the specified time date If no data is stored in the meter for the specified date it will send out data from the nearest date backwards in time Therefore the system should check the date sent out in the telegram to verify that it is the requested date that is sent out If no data is stored in the meter for the specified date or any date backwards in time all data in the telegram will have status byte marked as no data available 15 hex Note that manufacturer specific coding of the status information is used to indicate the following status e Interval are too short or too long e Data overflow in interval e Power outage occurred during the interval Page 108 of 137 DELTAplus meter User s Manual Rev When one or several of these status events occurred during the interval 3 the extra VIFE s FF FE 0x are sent out where x is bit 3 0 and have the following meaning if set Bit 3 data overflow in interval bit 2 power outage occurred during interval bit 1 short interval bit 0 long interval If the data item read is normal with no specific status associated with it no status VIFE or 0 will be sent out If the status
73. LTAplus meter indicates being in this mode by flashing the triangle V If no button is pressed after entering Instrumentation mode the different display items will be automaticaly displayed one at a time in sequence If the scroll button is pressed shortly it single steps hand symbol C on and each item can be viewed longer time The instrumentation quantities are displayed in primary form that is the measured secondary values are multiplied by the transformer ratios when displayed on the LCD A long scroll will take the meter back to Normal mode Below is described the information shown in nstrumentation Mode 2 7 3 1 Power The format of the power displayed depends on the magnitude The table below shows the format for different magnitudes Power kW kvar kVA Power format displayed P lt 1 W var VA no decimal 1 lt P lt 10 kW kvar kVA with 2 decimals 10 lt P lt 100 kW kvar kVA with 1 decimal 100 lt P lt 1000 kW kvar kVA no decimal 1000 P 10000 MW Mvar MVA with 2 decimals 10 000 P 100 000 MW Mvar MVA with 1 decimal 100 000 P 1 000 000 MW Mvar MVA no decimal The per element and total active power are displayed on all meters In combined meters also the per element and total reactive power and total apparent power are displayed The power is presented in the format Px XXXX unit where x is the element number 1 3 or t for the total power for example P2 2293 var for the element 2 reactive po
74. NTATION The instrumentation functions in the DELTAplus meter with all measurements enabled consist of measuring frequency per phase reading of voltage current phase angle and current harmonics per phase and total reading of active reactive apparent power power factor power factor angle and active quadrant It also includes displaying some of these quantities on the LCD and communicating the results over the communication interface s Normally only a subset of the instrumentation quantities are displayed on the LCD and sent out over the communication interface s All measurements are done in parallell and updated approximately once a second except for the current harmonics where the harmonics numbers 2 9 are measured sequentially one at a time one harmonic number approximately once a second All instrumentation data accuracy are defined within the voltage range 20 of the stated nominal voltage and within the current range 5 of the base current to the maximum current The accuracy of all instrumentation data except the voltage and current phase angles and current harmonics are the same as the IEC 62053 21 stated energy metering accuracy The accuracy for the voltage and current phase angles are 2 degrees The accuracy for the current harmonics varies with the harmonic amplitude and the harmonic number and are are valid provided that no harmonics above 500 Hz exists Harmonic 1 96 5 lt 10 lt 20
75. No Size in bytes Value Description 1 1 68 Start character 2 1 OE L field calculated from C field to last user data 3 1 OE L field repeated 4 1 68 Start character 5 1 53 73 C field SND UD 6 1 Xx A field address 7 1 51 Cl field data send LSB first 8 1 07 DIF size 8 byte integer 9 1 FD VIF extension of VIF codes 10 1 16 VIFE password 11 18 8 Password 19 1 XX CS checksum calculated from C field to last data 20 1 16 Stop character All commands protected by password must be preceded by this command The sequence when sending a password protected command is thus The password is sent with the Send password command The meter answers with acknowledge The command is sent The meter answers with acknowledge Note that it is not possible to first send the password command followed by several password protected commands In that case only the first password protected command will be accepted Note also that it is not allowed to send any other command between the Send password and the command for example an initialize command There is a timeout of 2 seconds between the send password and the command If the delay between the send password and the command is bigger than 2 seconds the command is not accepted If this timeout time of 2 seconds is not enough it is possible to prolong it in steps of seconds by inserting extra DIFE s in the command where th
76. ONMENT DATA AND TESTS Operating temperature range 40 C to 55 C Storage temperature range 40 C to 70 C Humidity 75 yearly average 95 on 30 days year Resistance to heat and fire Terminal 960 C cover 650 C IEC 60695 2 1 3 2 6 PULSE OUTPUT STANDARD ON ALL METERS EXCEPT LON MBUS Current 0 100 mA Voltage 0 247 V AC 350 V DC polarity independent Terminal wire area 0 2 5 except Combined meters 0 0 5 mm Pulse output freq programmable primary registering Pulse width 100 ms as standard Recommended tightening torque 0 5 Nm 3 2 7 TRANSFORMER RATIOS Programmable voltage ratio VT 1 9999 Programmable current ratio CT 1 9999 Max total transformer ratio VT CT 999999 3 2 8 VISIBLE PULSE INDICATOR Red LED with frequency 5000 imp kWh secondary registering Pulse width 40 ms 3 2 9 STANDARDS IEC 62052 11 IEC 62053 21 class 1 IEC 62053 23 class 2 IEC 62054 21 Measurement instrument directive MID category A amp B electrical environmental class E2 and electrical environmental class M2 EN 50470 1 EN 50470 3 category A amp B Pulse output according to IEC 62053 31 SO DIN 43864 3 2 10 ELECTROMAGNETIC COMPATIBILITY EMC AND INSULATION PROPERTIES According to IEC 62052 11 IEC 62053 21 and IEC 62053 23 Impulse voltage test 6 kV 1 2 50us IEC 600 60 Surge voltage test 4 kV 1 2 50us IEC 61000 4 5 Fast transient burst test 4 kV IEC 61000 4 4 Immun
77. P O01 e 87 6 2 1 TECHNICAL DATA ADDITIONS TO THE BASIC 87 6211 Communication ob Jects seien he dee ei aere dieci diee t eR 87 6 2 2 COMMISSIONING OPERATION isses r eteron 87 6 2 3 INSTALLATION E 87 I assistens o MEM MEE 87 8 SERVICE AND nennen nnne nennen nnn 87 8 1 0319 V LO PR 87 8 2 87 AA EP ED PADDED Page 5 of 137 DELTAplus meter User s Manual Rev 1 GENERAL This manual contains information about the DELTAplus meter which is a family of electronic electricity meters manufactured by ABB Automation Technologies AB The purpose of this manual is to give the user a good overview and understanding of the many functions and features the DELTAplus meter offers It also describes general metering aspects The end goal is to help the user to use the meter in the most optimal and correct way and to give the proper service and support to maintain the highest stability and lifetime The degree of the DELTAplus meter functions is controlled by its hardware electronic boards mechanics etc software resided in a small computer inside the meter and the meter type specific programming done when it is produced stored in a non volatile EEPROM memory Features both hardware and software which are no
78. VOLTAGE CURRENT INPUTS 2 ertet tette ou eee as Soe denies Rec ete reb dne 46 3 1 2 GENERAL 46 3 1 3 MECHANICAL DATA AND TESTS 46 3 1 4 ENVIRONMENT DATA AND TESTS 46 3 1 5 PULSE OUTPUT STANDARD ON ALL METERS EXCEPT LON MBUS 46 3 1 6 VISIBLE PULSE INDICATOR etse ec ERROR RE re 46 3 1 7 STANDARDS 47 3 1 8 ELECTROMAGNETIC COMPATIBILITY AND INSULATION PROPERTIES 47 32 TRANSFORMER RATED METER cccssccscsssccssenssscssssccsssssessssssesssssessesssssessssssesessnesscssesseseessoes 47 3 2 1 VOLTAGE INPUTS C 47 3 2 2 CURRENT INPUTS ae E E E E EEEE EE E R EEE 47 3 2 3 GENERAL EEKE EE E E EE V E E RE E EE 47 3 2 4 MECHANICAL DATA AND 47 3 2 5 ENVIRONMENT DATA AND TESTS 48 3 2 6 PULSE OUTPUT STANDARD ON ALL METERS EXCEPT LON 48 AA EP ED PADDED Page 3 of 137 DELTAplus meter User s Manual Rev TABLE OF CONTENTS 3 2 7 TRANSFORMER 48 3 2 8 VISIBLE PULSE INDICATOR rer ettet et eterne th eer reete o ere Re rH RR REPRE ETE 48 3 2 9 STANDARDS Sen Saeki eel bes ain torte eeiam ame 48 3 2 10 ELECTROMAGNETIC COMPATIBILITY EMC AND INSULATION PROPERTIES 48 33 SOP TIONS c 48 3 3 1 INPUTS
79. VOLTAGE TRANSFORMER 3 element transformer rated meter Single phase transformer rated meter 1123 415 67 9 11 Fig 4 6 Wiring diagrams for transformer rated meters with voltage transformers 54 of 137 DELTAplus meter User s Manual Rev 4 2 4 INPUTS OUTPUTS pem INP1 MIRI E INP1 INP2 OUT1 OUT1 OUT2 ae INP2 TP Tae Te ee Fig 4 7 Input output variants 4 2 55 TARIFF INPUTS Fig 4 8 Tariff input connection diagram 426 PULSE OUTPUTS kWh v kWh r L3 2 eje 20 24 22 21 20 Fig 4 9 Pulse output connection diagram 427 COMMUNICATION For information regarding installation of communication see chapter 6 4 3 INSTALLATION TEST In all DELTAplus meters an automatic installation check is performed to detect an incorrect installation The test is run automatically on a regular basis in the background approximately every second The installation check is a very good aid to find and correct installation errors However it is still the installer that has the final responsibility that the meter is installed correctly It should be pointed out that there are combinations of incorrect connections which fall within the normal allowed conditions
80. Variable length ASCII 1110 12 digit BCD 6 Coding of the Data Field e Extension Bit is set when next byte is a DIFE 3 p pp T Extension Storage Number Bit Structure of the Data Information Field Extension DIFE e Unit is used on power and energy values to tell what type of power energy the data is It is also used to define the number of inputs outputs and to specify sign of offset when accessing event log data Tariff is used on energy values to give tariff information 0 Total 1 4 Tariff 1 4 Storage Number is set to 0 in values read to indicate momentary values and storage number bigger than 0 to indicate previously stored values values stored at some timepoint in the past Value Information Block VIB AA 1 PADDED Page 75 of 137 DELTAplus meter User s Manual Rev The VIB follows a DIF or DIFE without a set extension bit It contains one Value Information Field VIF and is in some cases expanded with up to 10 Value Information Field Extensions VIFE tz e s 4 3 2 M To Value Information Bit Structure of the Value Information Field VIF Value Information contains information about the value unit status etc The Extension Bit is set when next byte is a VIFE In case VIF or VIFE FFh the next VIFE is manufacturer specific The manufacturer specific VIFE has the same construction as a VIF If the extension bit of the manufacturer specific VIFE is set a
81. a phase shift between current and voltage due to the fact that the load has a more or less reactive component e g motors that have an inductive component etc A reactive load will increase the current which means that the power source generator and the size of the power lines have to increase which in turn means higher cost for the utility A higher current also means that the line losses increase Because of that the maximum permissible phase shift is sometimes governed in the terms of the consumers contract with the electricity supplier If the consumer exceeds some specified maximum reactive load they will be liable to an extra charge This type of contract will require a utility meter that measures reactive energy and or power Also from the customer point of view it may be of big interest to measure reactive energy power as it gives knowledge on the nature of the load how big different loads are and how they vary in time This knowledge can be used in the planning how to decrease the reactive power energy to decrease the electricity bill This can be done for example by installing compensation equipment usually in the form of capacitor banks or distribute the load more evenly in time Resistive loads don t give rise to any phase shifts Inductive loads have phase shift in one direction with the current lagging the voltage while capacitive loads produces a phase shift in the opposite direction with the current leading the voltage see fig 5 1 belo
82. adrant 2 the load is capacitive and active energy is exported and reactive energy is imported In quadrant 3 the load is inductive and active and reactive energy is exported In quadrant 4 the load is capacitive and active energy is imported and reactive energy exported 5 2 SINGLE PHASE METERING In a 2 wire installation a single phase meter is used Normally the 2 wires are a phase voltage and the neutral see fig 5 3 below where a direct connected single phase meter is measuring the active energy E consumed by a load Meter T Load U 0 10 dt Fig 5 4 Single phase measurement The active energy consumed by the load is the product of momentary voltage and current integrated over the desired measuring time period see mathematical formula above in the picture In the case where no harmonics is present and the rms value of the voltage and current is constant the active power can be expressed as P Url coso where is the phase angle between the voltage and the current In three phase systems the single watt meter method only gives correct results in a balanced system same voltage current and power factor in all phases This method should not be used for accurate AA 1 Page 60 of 137 DELTAplus meter User s Manual Rev measurement but can be used when high accuracy is not needed to simplify the measurement and reduce the cost E 3 U3 t 13 t dt Fig 5 5 Single phase measurement in 3 pha
83. al active power Reactive power nvoReactPwrTot Instantaneous total reactive power Apparent power nvoAppPwrTot Instantaneous total apparent power Voltage L1 N nvoVoltL1_N Instantaneous voltage between L1 and neutral Voltage L2 N nvoVoltL2 N Instantaneous voltage between L2 and neutral Voltage L3 N nvoVoltL3 N Instantaneous voltage between L3 and neutral Voltage L1 L2 nvoVoltL1 L2 Instantaneous voltage between L1 and L2 Voltage L2 L3 nvoVoltL2 L3 Instantaneous voltage between L3 and L2 Current L1 nvoCurrentL1 Instantaneous current in the L1 phase Current L2 nvoCurrentL2 Instantaneous current in the L2 phase Current L3 nvoCurrentL3 Instantaneous current in the L3 phase Power factor nvoPowerFact Instantaneous total power factor To reset the pulse counter a value shall be sent to nviCounterRst SNVT_reg_val with raw 0 unit RVU_NONE and nr_decimals 0 Register Network variable name Variable type Description Tariff nviTariff SNVT_count Set new tariff range 1 4 nvo TariffFb Current tariff Input nvolnputState SNVT lev disc Current state nvoStoredState Stored state nviClrStdState Clear stored state with ST_ON Output nviOutput SNVT_lev_disc Set state ST ON ST OFF nvoOutputFb Current state Error flags nvoErrorFlags 8 8 byte Internal error flags described in 0 Internal update timer ncilnternalUpdT SNVT_time_sec Data update interval in se
84. alling direction and to identify the sender of information in the receiving direction The size of this field is one byte and can therefore take values from 0 to 255 e The address 0 is given to meters at manufacturing e The addresses 1 to 250 are given to the meters as individual primary addresses The address can be set either via the bus secondary addressing or via the buttons see 6 2 5 2 The primary address can be viewed in Alternative Mode and is displayed as Adr xxx with xxx being the primary address e The addresses 251 and 252 are reserved for future use e The address 253 FDh is used by the secondary addressing procedure e The address 254 FEh is used for point to point communication The meter replies with its primary address e The address 255 FFh is used for broadcast transmissions to all meters None of the meters replies to a broadcast message Control Information Field Cl field The Cl field codes the type and sequence of application data to be transmitted in the frame Bit two counting begins with bit 0 value 4 called M bit or Mode bit in the Cl field gives information about the AA EP ED Page 73 of 137 DELTAplus meter User s Manual Rev used byte sequence in multi byte data structures For communication with the DELTAplus meter the Mode bit shall not be set Mode 1 meaning the least significant byte of a multi byte record is transmitted first Cl Application
85. arding which commands is affected by the write protection level is found below in the command description Commands not affected by the write protection level only require a correct message with correct address syntax and checksum to be accepted It must also of course be a meter which have the functionality associated with the command It must for example be a meter with internal clock for the set date time command to have any effect Having a password with only zeros in the open by password level have the same effect as if it is open If password is used and it is forgotten the meter must be opened with the buttons When the meter is open a new password can be sent to the meter with the set password command 6 1 4 2 1 Set tariff In tariff meters where the tariffs are controlled via communication the active tariff is set by the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 07 L field calculated from C field to last user data 3 1 07 L field repeated 4 1 68 Start character 5 1 53 73 C field SND UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 01 DIF size 8 bit integer 9 1 VIF next byte is manufacturer specific 10 1 13 VIFE tariff 11 1 XX New tariff 12 1 XX CS checksum calculated from C field to last data 13 1 16 Stop character This command is not affected by the write protecti
86. ase voltage connected to meter neutral terminal Hints Incorrect connection of phase voltages and neutral 140 Time not set Hints Set time with buttons or via communication 141 Date not set Hints Set date with buttons or via communication 200 203 Internal error Contact supplier EP ED PADDED Page 57 of 137 DELTAplus meter User s Manual Rev 5 MEASUREMENT METHODS There are a lot of different ways to measure energy This chapter contains information about measurement theory and the most common measurement methods It can be used to understand the meter behavior better and to pick the correct measurement method with respect to cost and accuracy For information about the specific internal measurement methods used in the different DELTAplus meters see chapter 2 In many households a single phase connection is used and a single phase meter can be used In a 3 phase system with a current carrying neutral conductor the 3 watt meter method is needed for a correct measurement and for billing purposes this is in most cases is a requirement High voltage installations often have no current carrying neutral and therefore the two watt meter measurement method can be used In many cases it is desired to simplify the measurement and or to reduce the cost In these cases simplified methods can be used of which the most common methods are mentioned below These methods most often require a balanced load which means that the impedance is
87. ation is handled by the main board microcontroller and the M bus board contains a transceiver that converts the signals to M bus levels All 3 communication buses are galvanically isolated from the rest of the meter electronics 2 14 DELTAPLUS MEASUREMENT METHODS The metering calculation in the meter is done by the microcontroller The DELTAplus meter exist in 3 basic versions single phase 2 element and 3 element meter The formulas used when calculating the active energy is as follows Single phase meters U is a calibration constant the voltage the current and the phase angle between the voltage and current 2 element meters K1 U1 U2 I1 K2 U3 U2 1 K1 and K2 are calibration constants U1 U3 the phase voltages 11 and 13 are the phase 1 and phase currents and 1 and 2 are the phase angles between the voltage and current in each element 3 element meters K1 U1 11 K2 U2 12 U3 1 cos 3 K1 K3 are calibration constants U1 U3 the phase voltages 11 13 the phase currents and 1 93 are the phase angles between the voltage and current in each element The formulas for calculating the reactive energy are the same except that all cos factors are changed to sing The DELTAplus meter only registers total positive energy If the total energy is negative the registers are not affected stands still For more information r
88. ceived correctly or that the address does not match The meter indicates to the master that there is more data in the next telegram by sending 1Fh as the last user data 6 1 3 2 1 Selection and Secondary Addressing It is possible to communicate with the meter using secondary addressing The secondary addressing takes place with help of a selection wl i ada Structure of a telegram for selecting a meter The master sends a SND UD with the control information 52h to the address 253 FDh and fills the specific meter secondary address identification number manufacturer version and medium with the values of the meter that is to be addressed The address FDh and the control information 52h is the indication for the meter to compare the following secondary address with its own and to change into the selected state should it match In this case the meter answers the selection with an acknowledgement E5h otherwise it doesn t reply Selected state means that the meter can be addressed with the bus address 253 FDh During selection individual positions of the secondary addresses can be occupied with wildcards Such a wildcard means that this position will not be taken into account during selection In the identification number each individual digit can be wild carded by a wildcard nibble Fh while the fields for manufacturer version and medium can be wild carded by a wildcard byte FFh PADDED Page 79 of 137 DELTAplus meter User
89. conds Allowed range 10 600 seconds Reset node after modifying Page 134 of 137 DELTAplus meter User s Manual Rev 6 2 2 COMMISSIONING OPERATION Before the meter is commissioned the service LED is flashing after commissioning it is off 6 23 INSTALLATION Cable type Wire dia AWG Roop nF km Vprop of c Belden 85102 single twisted pair 1 3 mm 16 28 56 62 stranded 19 29 unshielded 150 C Belden 8471 single twisted pair 1 3 16 28 72 55 stranded 19 29 unshielded 60 Level IV 22 AWG twisted pair 0 65 mm 22 106 49 67 Typically solid amp unshielded JY St 2x2x0 8 4 wire helical twist 0 8 mm 20 4 73 98 41 solid shielded If a shielded cable is used the shield should be connected to earth ground via a single 470kQ 1 4 watt lt 10 metal film resistor to prevent static charge build up Connect the meter to the LonWorks network on the screw terminals according to fig 6 3 below Green Red LED Service pin CAL11MOL5 8888888 ABB Cewe LonWorks network polarity insensitive Fig 6 3 Connecting LonWorks interface Page 135 of 137 DELTAplus meter User s Manual Rev 7 ACCESORIES Accessory ABB part number Communication adapter for M Bus Communication adapter for RS232 Communication adapter for Ethernet Communication adapter for LON PLC A band Communication adapter for LON PLC C band
90. current harmonics 12 1 Phase number 1 3 13 1 XX CS checksum calculated from C field to last data 14 1 16 Stop character The meter will start sending out harmonic data from the requested phase If a phase number not supported by the meter is requested for example phase 2 or 3 in a single phase meter all data in the telegram will be marked not available Below are a number of commented practical examples of a number of current harmonic readouts where data sent to and read from the meter is shown All data is in hexadecimal format Comments after sent or received bytes are preceded with a semicolon Readout of all current harmonic data from a 3 element meter System sends harmonic data read request command 68 07 07 68 73 fe 51 00 9 1b 5 16 Meter sends out acknowledge E5 System sends out request UD2 10 7b fe 79 16 Meter sends out data telegram 68 73 73 68 08 00 72 00 00 00 00 42 04 05 02 00 00 00 Data header 02 ed ff 81 8 00 16 01 Total current harmonic distorsion for phase 1 27 8 95 02 ff ed ff 81 8 02 00 00 2 current harmonic distorsion 0 2 96 02 ff ed ff 81 ff 8 03 c2 00 3ird current harmonic distorsion 0 2 95 02 ff ed ff 81 ff 8 04 03 00 02 ff ed ff 81 ff 8 05 b6 00 02 ff ed ff 81 ff f8 06 03 00 02 ff ed ff 81 ff 8 07 53 00 02 ff ed ff 81 f 08 03 00 02 ff ed ff 81 ff f8 09 02 00 1f 000000000000 00 00 00 68 16 Sys
91. d while the pulse frequency is displayed in set mode 26 of 137 DELTAplus meter User s Manual Rev Ti the hand symbol will flash and you go through all values with the scroll button short scroll and select the preferred value with the set button 2 7 4 4 Reset of energy registers Allows you to reset energy registers This is an option and is normally present only in some special meters When the set button is pressed while rESEt is displayed in set mode x the hand C will start flashing If then the set button is pressed all registers except the total are set to zero both active and reactive 2 7 4 5 Primary address Allows you set the M bus primary address When the set button is pressed while the primary address is displayed in set mode 27 of 137 DELTAplus meter User s Manual Rev the hand symbol starts flashing and the first digit in the address is displayed always starts with 0 The first digit is increased by 1 for every short press on the scroll button The chosen value is confirmed by pressing the set button The same procedure is then done for the 10 digit and finally the 100 digit When the 100 digit is confirmed and the meter will start to use the new address It is only possible to select valid addresses 0 250 A s
92. displayed in meters with pulse output s as P where is the frequency in impulses kWh kvarh 21 of 137 DELTAplus meter User s Manual Rev 2 7 2 6 Baud rate The M bus baud rate is displayed in meters with electrical M bus as bd xxxx where xxxx is the baud rate in bits seconds 2 7 2 7 Primary address The M bus primary address is displayed as Adr xxx where xxx is the primary address 2 7 2 8 Communication status The M bus communication status is displayed as C xxxxx where xxxxx are different codes that reflect what s happening on the bus In meters with electrical M bus it displays the status of the electrical M bus and in all other meters the status of the the infrared IR communication port As long as there are no messages addressed to the meter C is displayed Note that messages on the bus with different baud rate than the meter baud rate or messages addressed to other meters will not be displayed displayed This can be used as an aid when trouble shooting communication When a message addressed to the meter is detected it displays C A x while communicating The letter A stands for that the meter is addressed and x denotes different internal communication states Possible states 1 Idle waiting for command 2 3 Receiving states 4 7 Transmitting states When errors are detected C Erxxx is displayed where xxx is a number t
93. e and time is set by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 OB L field calculated from C field to last user data 3 1 0B L field repeated 4 1 68 Start character 5 1 53 73 C field SND_UD 6 1 A field address 7 1 51 Cl field data send LSB first 8 1 DIF size 12 digit BCD 9 1 6D VIF time date 10 15 1 XXXXXXXXXXXX Time and date sec min hour day month year 16 1 XX CS checksum calculated from C field to last data 17 1 16 Stop character This command is affected by the write protection level set Page 102 of 137 DELTAplus meter User s Manual Rev It is also possible to set the date and time having the date and time coded according to the M bus data type F Byte No Size in bytes Value Description 1 1 68 Start character 2 1 09 L field calculated from C field to last user data 3 1 09 L field repeated 4 1 68 Start character 5 1 53 73 C field SND UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 04 DIF size 32 bit integer 9 1 6D VIF time date 10 13 1 XXXXXXXX Time and date Min hour day month year coded accorded to M bus datatype F Minutes in bits 0 5 Valid values 0 59 Hours in bits 8 12 Valid values 0 23 Day in bits 16 20 Valid values 1 31 Month in bits 24 27 Valid values 1 12 Year in bits 21 23 and 28 31 msb bits
94. e the registers are stored when the meter starts up after the power outage and the date time stamp will be set to the date time when the meter is powered up If the power outage lasts over more than one monthly change no monthly values will be stored for the months passed while the meter was not powered The number of monthly values to be stored are programmable from 0 up to 31 Note that changing the number of monthly values will erase all monthly values It will also erase all load profile maximum demand and event log data due to the fact that data for these functions are stored after monthly values in the EEPROM and changing the number of monthly values change the addresses for data aftercoming data and requires reset of this data It is possible to erase all monthly values by sending a special command for details see chapter 6 If the maximum number of values have been stored and new values are stored the oldest values will be overwritten As mentioned above the monthly values are stored at a monthly change Therefore when adjusting time it should be avoided to change backwards into a previous month which will then trigger storage of monthly values both when going into the previous month and when going into the new month The monthly values are not displayed on the LCD and can only be read via communications For details see chapter 6 No monthly values will be stored if date and or time is not set 2 12 3 LOAD PROFILE In the load
95. e unit bits in the DIFE s controls the extra timeout see section 6 1 3 1 1 for description of a DIFE The unit bit in the first DIFE have value 1 2 the unit bit in the second DIFE have value 2 25 the unit bit in the third DIFE have value 4 25 etc Page 101 of 137 DELTAplus meter User s Manual Rev Examples Password command with password 1122334455667788 primary address 9 1 second extra timeout 68 Of Of 68 73 09 51 87 40 fd 16 11 22 33 44 55 66 77 88 Ob 16 Password command with password 1122334455667788 primary address 9 3 seconds extra timeout 68 10 10 68 73 09 51 87 40 fd 16 11 22 33 44 55 66 77 88 cb 16 6 1 4 2 17 Set password Password is set by the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 OF L field calculated from C field to last user data 3 1 OF L field repeated 4 1 68 Start character 5 1 53 73 C field SND UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 07 DIF size 8 byte integer 9 1 FD VIF extension of VIF codes 10 1 96 VIFE password 11 1 00 write replace 12 19 8 Password 20 1 XX CS checksum calculated from C field to last data 21 1 16 Stop character Note that if the meter is password protected the old password must first be sent before the new is sent 6 1 4 2 18 Set date and time The dat
96. ecimal format If no data is stored in the meter equal to or older than the specified date all data in the telegram will have status byte marked as no data available 15 hex After having read a telegram with maximum demand data it is possible to continue to read next stored telegram backwards in time by continue sending REQ_UD2 s The last DIF in the telegram tell if there are more data or not 1F hex when more data exists and OF hex if no more data exist All maximum demand data stored for a measurement period will be sent out in each telegram The data sent out is the interval length the maximum demand and date time stamp for the maximum for all quantities and a date time stamp for the end of the measurement period Each maximum demand is followed by the date time stamp for that maximum where the time given is the end of the interval The date time information is sent out in format 6 byte bcd in order second minute hour day month and year The data for the currently pending period will be sent out with storage number set to 0 the most recent stored historical values will have storage number 1 the next set of historical values will have storage number 2 etc If data have not been generated for a quantity the maximum is set to 0 and the date time is set to 00 00 00 00 00 00 This is the case for the currently pending period before any maximum demand have been stored that is while the very first interval in a measurement period
97. egarding measurement methods see chapter 5 Page 44 of 137 DELTAplus meter User s Manual Rev 2 15 DIMENSIONS Below the dimensions for the direct and transformer rated meter are displayed The 2 pictures to the left are for the transformer rated meter and the picture to the upper right is for the direct connected meter The side view dimensions given is applicable to all types The dimensions in the direct connector terminal block conform to the standard DIN 43857 134 6 7 9 Wi 7 12 N sil 0 1 un 1 1 1 5 8 75 i i 0 J Fig 2 2
98. eld address 7 1 51 Cl field data send LSB first 8 1 00 DIF size no data 9 1 VIF next byte is manufacturer specific 10 1 9 VIF extension of manufacturer specific vife s next vife specifies actual meaning 11 1 VIFE specifies data to be cleared 82 Maximum demand 83 Monthly values 84 Load profile 85 Event log 12 1 07 VIFE clear 13 1 XX CS checksum calculated from C field to last data 14 1 16 Stop character This command is affected by the write protection level set 6 1 4 2 21 Freeze maximum demand The maximum demand values will be freezed and a new period started by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 08 L field calculated from C field to last user data 3 1 08 L field repeated 4 1 68 Start character 5 1 53 73 C field SND_UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 00 DIF size no data 9 1 VIF next byte is manufacturer specific 10 1 9 VIF extension of manufacturer specific vife s next vife specifies actual meaning 11 1 82 specifying maximum demand 12 1 OB VIFE freeze 13 1 XX CS checksum calculated from C field to last data 14 1 16 Stop character This command is affected by the write protection level set Page 104 of 137 DELTAplus meter User s Manual Rev 6 1 4 2 22 Set write access level The wr
99. elected primary address can be used both for the optical port and the electrical M bus if present 2 7 4 6 Baud rate Allows you set the M bus electrical bus baud rate only in meters with electrical M bus When the set button is pressed while the baud rate is displayed in set mode the hand symbol nca begins flashing and you can now go through all 6 values 300 9600 baud with the short scroll button and select the preferred value with the set button 2 7 4 7 Time Allows setting of the time When the SET button is pressed while the time hour minute second is displayed in Set mode 28 of 137 DELTAplus meter User s Manual Rev The hour digits are increased by 1 for every short press possible values 0 23 on the SCROLL button The chosen value is confirmed by pressing the SET button The minute tens digit then starts flashing and is increased for every short press possible values 0 5 on the SCROLL button The chosen value is confirmed by pressing the SET button The minute unit digit then starts flashing and is increased for every short press possible values 0 9 on the SCROLL button The chosen value is confirmed by pressing the SET button The second digits then starts flashing and is set to zero at every short press on the SCROLL button The second digits are c
100. enen bebes erat 34 2 10 2 INDICATION OF ACTIVE 34 2 103 INPUT COMING x 34 2 11 PULSE OUTPUTS REPRE 35 2 11 1 PULSE FREQUENCY AND PULSE 35 2 12 INTERNAL CLOCK AND TIME DEPENDANT FUNCTIONG scsscsssssssscssssccssesssseseeseseseseee 36 2 12 1 INTERNAL CLOCK Dente 36 2 12 2 MONTHLY VALUES eren tete etr o eren 36 2 123 LOAD PROFILE 37 2 124 MAXIMUM DEMAND 38 2125 39 2 126 TARIFF CONTROL 1 39 2 12 7 OUTPUTS CONTRODIBY CLOCK 40 2 13 DL LOU C0 COURRIER 41 24394 MAIN BOARD rm 41 2 13 2 INPUT OUTPUT BOARDS castes ette to tte teens Sunes teeth exes EE ARE OER etse pene 42 2 133 COMMUNICATION 5 nennen ren rennen trennen nennen 43 2 14 DELTAPLUS MEASUREMENT METH ODS ceres eee eese eene seen tn seta so seta sosta 44 2 15 DIMENSIONS s 45 3 TECHNICAL BATES nid MMOL DUE b DUI DNE CURIE 46 3 1 DIRECT CONNECTED METER esee esee een enses ense tn sunto sonata sesto stesso 46 3 1 1
101. er character Start Check Sum Stop characters per telegram format e The second Start character the parity of the two field lengths and the number of additional characters received L Field 6 with a long frame e fthe received data is reasonable The time between a confirm or respond message from the meter until the next message sent to the meter must be at least 20 ms Send Confirm Procedure SND_NKE This procedure serves to start up after the interruption or beginning of communication After receiveing NKE the meter will always send out the 1 st telegram after receiving REQ_UD2 see description below If the meter was selected for secondary addressing it will be deselected The value of the frame count bit FCB is cleared in the meter i e it expects that the first telegram from a master with FCV 1 contains an FCB 1 The meter either confirms a correct reception with the single character acknowledge E5h or omits the confirmation if it did not receive the telegram correctly SND_UD This procedure is used to send user data to the meter The meter either confirms a correct reception with the single character acknowledge E5h or omits the confirmation if it did not receive the telegram correctly Request Respond Procedure REQ UD2 RSP UD The master requests data from the meter using the UD2 telegram The meter will either transfer its data with UD or gives no response indicating that the request has not been re
102. er to switch on off the outputs at specific switchpoints in time It is possible to define up to 4 different day types and 4 different seasons with different switch schemes for each combination of day type and season The day types are defined on a weekly basis and the season switches are defined on a yearly basis It is possible to define yearly cyclic dates where a specific day type or season switch is specified It is also possible to define specific dates where a specific day type is specified The daytypes specified by specific dates have highest priority after which comes the daytypes specified by yearly cyclic dates and the weekly specified daytypes have lowest priority If date and or time is not set a programmable default state for the ouputs will be active The output state is not displayed on the LCD and can only be read via communication se chapter 6 for details Page 40 of 137 DELTAplus meter User s Manual Rev 2 13 ELECTRONICS The electronics inside the meter consist of a main board always used and optionally an input out board and a communication board 2 13 1 MAIN BOARD Below a block diagram of the meter main board is displayed Phase voltage inputs IR Comm port gt i Ure 5 U Te 3 phase power supply N Scroll o o Set Resistor dividers l H c b Load resistors Multiplexer amp
103. error Bits 6 8 Unused Bit9 Internal communication error Bit 10 No data available Bit 11 Hardware error Bit 12 Invalid time Bits 13 15 Unused Meter ID nvoMeterlD Meter serial number 8 digits ASCII Installation check nvilnstChkClr Reset installation check result with ST_ON Page 133 of 137 DELTAplus meter User s Manual Rev Utility Data Logger registers variable type SNVT_reg_val_ts Register Network variable name Description Active energy total nvoAEnergyTot Total cumulative Active Energy Active energy tariff 1 nvoAEnergyTf1 Cumulative Active Energy Tariff 1 Active energy tariff 2 nvoAEnergyTf2 Cumulative Active Energy Tariff 2 Active energy tariff 3 nvoAEnergyTf3 Cumulative Active Energy Tariff 3 Active energy tariff 4 nvoAEnergyTf4 Cumulative Active Energy Tariff 4 Reactive energy total nvoREnergyTot Total cumulative Reactive Energy Reactive energy tariff 1 nvoREnergyTf1 Cumulative Reactive Energy Tariff 1 Reactive energy tariff 2 nvoREnergyTf2 Cumulative Reactive Energy Tariff 2 Reactive energy tariff 3 nvoREnergyTf3 Cumulative Reactive Energy Tariff 3 Reactive energy tariff 4 nvoREnergyTf4 Cumulative Reactive Energy Tariff 4 Transformer ratio nvoTrfRatio Read transformer ratio Counter nvoCounter Value of the pulse counter nviCounterRst Reset pulse counter Active power nvoActPwrTot Instantaneous tot
104. es 188 1 1A VIFE digital output 189 1 XX Output 2 current state 190 1 OF DIF indicating that this is the last telegram 191 216 26 000000000000000 PAD bytes 000000000000000 000000000000000 0000000 217 1 XX CS checksum calculated from C field to last data 218 1 16 Stop character AA EDEB 91 of 137 DELTAplus meter User s Manual Rev Example of the telegram all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 9C L field calculated from C field to last user data 3 1 9C L field repeated 4 1 68 Start character 5 1 08 C field RSP_UD 6 1 XX A field address 7 1 72 Cl field variable data respond LSB first 8 11 4 XXXXXXXX Identification Number 8 BCD digits 12 13 2 4204 Manufacturer ABB 14 1 02 Version 15 1 02 Medium 02 Electricity 16 1 XX Number of accesses 17 1 XX Status 18 19 2 0000 Signature 0000 no encryption 20 1 CE DIF size 12 digit BCD storage number bit 0 22 1 00 DIFE storage number bit 1 4 22 1 ED VIF for time date point 23 1 eB VIFE indicating end of period 24 29 6 XXXXXXXXXXXX Time and date sec min hour day month year 30 1 CE DIF size 12 digit BCD storage number bit 0 31 1 00 DIFE storage number bit 1 4 32 1 04 VIF for units kWh with resolution 0 01kWh 33 38 6 XXXXXXXXXXXX Active energy total 39 1 CE D
105. es backwards in time by continue sending 002 The last DIF in the telegram tell if there are more data or not 1F hex when more data exists and OF hex if no more data exist All monthly register values stored at the end of a period will be sent out in each telegram Beside the monthly register values a date time stamp for the end of the period is sent out in the telegram The date time information is sent out in format 6 byte bcd in order second minute hour day month and year If the data item read is normal with no specific status associated with it no status VIFE will be sent out or 0 will be sent out If the status is data error or no data available the standard M bus status coding values will be sent out 18 hex or 15 hex Page 118 of 137 DELTAplus meter User s Manual Rev The register values have same data and value information bytes dif dife s vif vife s as for the momentary register vales but with storage number bigger than zero to indicate that it is stored historical data Below are a number of commented practical examples of a number of monthly value readouts where data sent to and read from the meter is shown All data is in hexadecimal format Comments are preceded with a semicolon System sends read request command for maximum demand with date 1 st of july 06 68 0A 0A 68 73 51 02 FF F9 19 C1 07 89 16 Meter sends out acknowledge E5 System sends out request UD2 10 7B FE 79
106. ess level Allows setting of communication write access level 3 levels exist e Open displayed on the LCD In this level it is possible to give all types of user related commands to the meter without restrictions It should be mentioned that it is not possible to change any constants affecting the basic energy measuring accuracy e Open by password OPEn P displayed on the LCD In this level it is possible to give all types of user related commands after sending a correct password to the meter It should be mentioned that it is not possible to change any constants affecting the basic energy measuring accuracy e Closed CloSEd displayed on the LCD In this level the meter is closed for all user related commands When the SET button is pressed while the communication write access level is displayed in Set mode The communication write access level is changed for every short press on the SCROLL button The chosen level is confirmed by pressing the SET button If itis in any of the open levels it is also possible to set the write access level via communication For details see chapter 6 The communication write access level does not affect the reading of the meter and it is always possible to read data from the meter Information about which commands use the write access level protection are found in chapter 6 31 of 137 DELTAplus meter User s Manual Rev 2 8 INSTRUME
107. ge L2 Instantaneous phase angle voltage for L2 voltage L1 is reference Phase angle voltage L3 Instantaneous phase angle voltage for L3 voltage L1 is reference Phase angle current L1 Instantaneous phase angle current for L1 voltage L1 is reference Phase angle current L2 Phase angle current L3 Instantaneous phase angle current for L2 voltage L1 is reference Instantaneous phase angle current for L3 voltage L1 is reference Lalani Phase angle power Total Instantaneous phase angle for total power voltage L1 is reference Phase angle power L1 Instantaneous phase angle power for L1 voltage L1 is reference Phase angle power L2 Instantaneous phase angle power for L1 voltage L1 is reference Page 70 of 137 DELTAplus meter User s Manual Rev Register Description Phase angle power L3 Instantaneous phase angle power for L1 voltage L1 is reference Frequency Instantaneous line frequency Power factor Total Instantaneous total power factor Power factor L1 Instantaneous power factor for L1 Power factor L2 Instantaneous power factor for L2 Power factor L3 Instantaneous power factor for L3 Installation check Read result of and clear installation check Current quadrant Quadrants in which the meter is measuring element 1 3 and total Power fail counter Read and reset power fail counter Total po
108. hat varies depending on the error Possible error codes 301 Checksum error in received message 302 Write access not allowed 303 Syntax error protocol error in received message 304 Uart error for example parity error 305 Timeout error 306 Wrong password This display item will be displayed for 4 hours if the scroll button is not pressed short or long scroll or until power off It is displayed only in single step mode 2 7 2 9 LED reactive On combined meters it is possible to have the red LED energy indicator to flash in proportion to the reactive energy instead of the active energy which it normally does This is done by single stepping to the LED reactive display item When this is reached the text LEd rEA is displayed It will stay in this mode until 4 hours have passed if the scroll button is not pressed by short or long Scroll or a power outage occurs The pulse frequency for the reactive energy flashing is the same as for the active energy marked on the nameplate This item is not displayed in auto scroll 2 7 2 10 Input counter s The input counter registers are displayed with 7 digits maximum value 9 999 999 The unit which is displayed factory setting is normally r as in rotations or revolutions for input counter 1 and rh for input counter 2 2 7 2 11 Input status The current input status is displayed as InP1 X and InP2 X where X is or 1 1 means voltage applied to input
109. he requested day that is sent out If no data is stored in the meter for the specified date or any date backwards in time all data in the telegram will have status byte marked as data available 15 hex After having read a complete day of load profile data it is possible to continue to read next stored day record backwards in time by continue sending REQ_UD2 s The last DIF in the telegram tell if there are more data or not 1F hex when more data exists and OF hex if no more data exist The data will be sent out with 12 load profile values in each telegram This means that 2 telegrams must be read for 1 day of load profile values when the interval length is 60 minutes If the interval PADDED Page 107 of 137 DELTAplus meter User s Manual Rev length is 30 minutes 4 telegrams must be read and if the interval length is 15 minutes 8 telegrams must be read Beside the interval data the date time information for the day record and the interval length is sent out When the load profile data is read out as consumption per interval the register value at the start of the 1 st interval is also sent out The date time information is sent out in format M bus data type F which consist of 4 byte with bits 0 31 coded according to the following Minutes in bits 0 5 Valid values 0 59 Hours in bits 8 12 Valid values 0 23 Day in bits 16 20 Valid values 1 31 Month in bits 24 27 Valid values 1 12 Year in bits 21 23 and 28 31 msb bits
110. hod A detailed description with examples of reading load profile maximum demand monthly values and event log is found in chapter 6 Using SND_UD telegrams data can be sent to the meter The following is possible to perform with SND_UD telegrams e Set tariff Set primary address Change baud rate Reset power fail counter Reset power outage time register Set CT ratio Set VT ratio Set transformer ratio sets the CT ratio and is only implemented for backward compatibility Select status information on values Reset of stored state of inputs Reset of counters inputs Set outputs Set date and time Send password Set password Freeze maximum demand registers Set communication access level Set tariff source Suppress LCD error display Read request of load profile Read request of monthly values Read request of maximum demand Read request of event log Read request of current harmonics Read write load profile settings Read write monthly value settings Read write maximum demand settings Read write event log settings Read write miscellaneous user configurable settings 80 of 137 DELTAplus meter User s Manual Rev To change baud rate in the DELTAplus meter a SND_UD telegram is sent containing information about which baud rate to change to If the meter accepts the new baud rate it will acknowledge with the old baud rate After acknowledging the meter changes to the new baud rate If it does not detect a
111. ic number 38 39 2 XXXX 2 nd harmonic in percent with 1 decimal 40 1 02 DIF size 2 byte integer 41 1 FF VIF next byte is manufacturer specific 42 1 ED VIFE current harmonics 43 1 FF VIF next byte is manufacturer specific 44 1 8x VIFE phase x 45 1 FF VIF next byte is manufacturer specific 46 1 F8 Extension of manufacturer specific vife s next vife s used for numbering 47 1 03 Harmonic number 48 49 2 XXXX 3 rd harmonic in percent with 1 decimal 4 121 of 137 DELTAplus meter User s Manual Rev 50 1 02 DIF size 2 byte integer 51 1 FF VIF next byte is manufacturer specific 52 1 ED VIFE current harmonics 53 1 FF VIF next byte is manufacturer specific 54 1 8x VIFE phase x 55 1 FF VIF next byte is manufacturer specific 56 1 F8 Extension of manufacturer specific vife s next vife s used for numbering 57 1 04 Harmonic number 58 59 2 XXXX 4 th harmonic in percent with 1 decimal EP ED 122 of 137 DELTAplus meter User s Manual Rev Harmonic data continued Byte No Size in bytes Value Description 60 1 02 DIF size 2 byte integer 61 1 FF VIF next byte is manufacturer specific 62 1 ED VIFE current harmonics 63 1 FF VIF next byte is manufacturer specific 64 1 8x VIFE phase x 65 1 FF VIF next by
112. ime not set Two element meter Single phase meter Active energy Reactive energy U1 missing U2 missing U3 missing 0 Negative power for element 1 Negative power for element 2 Negative power for element 3 Negative power total Phase connected to neutral Primary load profile energy values Primary linstrumentation and maximum demand values Page 131 of 137 DELTAplus meter User s Manual Rev 6 1 5 INSTALLATION Cable type Max no of meters Max length JYStY N 2 0 8 250 350m Standard mains type 1 5mm 250 1000m For telephone cabling with 0 6mm diameter wires either the maximum distance or the maximum number of meters has to be halved Connect the meter to the M Bus network on the screw terminals according to the figure below e DAM13000 8888888 Q5 Fig 6 2 Connecting M Bus M Bus input polarity insensitive The baud rate and primary address can be set via the communication bus see section 6 1 4 or with the buttons see section 2 7 4 As an aid when trouble shooting there is a special communication display item in A ternative Mode in which the current communication status is displayed see section 2 7 2 8 Page 132 of 137 DELTAplus meter User s Manual Rev 6 2 LONWORKS LonWorks is a bus system for home and building automation It is a decentralized system with distributed intelligence LonWorks supports free topology and communication on variou
113. in format number of counts per interval Readout request of input 2 counter load profile profile profile in format counter register values at end of intervals Readout request of input 2 counter load profile in format number of counts per interval Readout request of maximum demand Readout request of monthly values Readout request of event log Data status for load profile o overflow p power outage during interval s short interval long interval Data The Data follows a VIF or a VIFE without the extension bit set Manufacturer Data Header MDH The manufacturer data header MDH is either made up by the character 1Fh that indicates that more data will follow in the next telegram or by OFh indicating the last telegram Check Sum The Check Sum is used to recognize transmission and synchronization faults It is calculated from the arithmetical sum of the bytes from the control field to the last user data without taking carry digits into account PADDED Page 78 of 137 DELTAplus meter User s Manual Rev 6 1 3 2 Communication process The Data Link Layer uses two kinds of transmission services Send Confirm SND CON Request Respond REQ RSP After the reception of a correct telegram the meter waits between 35 and 80ms before answering A received telegram is considered as correct if it passes the following tests Start Parity Stop bits p
114. is done by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 07 L field calculated from C field to last user data 3 1 07 L field repeated 4 1 68 Start character 5 1 53 73 C field SND UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 00 DIF size no data 9 1 FF VIF next byte is manufacturer specific 10 1 F9 VIF extension of manufacturer specific vife s next vife specifies actual meaning 11 1 1B VIFE specifies current harmonics 12 1 XX CS checksum calculated from C field to last data 13 1 16 Stop character The meter will send out harmonic data for one phase in each telegram which means 3 telegrams in a 3 element meter 2 telegrams in a 2 element meter and 1 telegram in a single phase meter Data sent out will be the total harmonic distorsion and the harmonics measured normally those with numbers 2 9 Note that the total harmonic distorsion is calculated from the harmonics measured and is thus not the true total harmonic distorsion which would require all harmonics up to infinite frequency to be measured If any harmonic have frequency above 500 Hz it will not be measured and will be marked not available see section 2 7 3 7 Data may temporarily be marked not available if there is disturbances on the net for example due to short voltage dips making the frequency measurement inva
115. is manufacturer specific 36 1 02 VIFE L2 37 39 4 XXXXXXXX Active power L2 40 1 04 DIF size 32 bit integer 41 1 A9 VIF for units W with resolution 0 01W 42 1 FF VIFE next byte is manufacturer specific 43 1 03 VIFE L3 44 46 4 XXXXXXXX Active power L3 47 1 84 DIF size 32 bit integer 48 1 80 DIFE Unit 0 49 1 40 DIFE Unit 1 gt xx10 2 50 1 29 VIF for units var with resolution 0 01var 51 53 4 XXXXXXXX Reactive power Total 54 1 84 DIF size 32 bit integer 55 1 80 DIFE Unit 0 56 1 40 DIFE Unit 1 gt xx10 2 57 1 A9 VIF for units var with resolution 0 01var 58 1 FF VIFE next byte is manufacturer specific 59 1 01 VIFE L1 60 62 4 XXXXXXXX Reactive power L1 63 1 84 DIF size 32 bit integer 64 1 80 DIFE Unit 0 65 1 40 DIFE Unit 2 1 2 xx10 2 66 1 A9 VIF for units var with resolution 0 01var 67 1 FF VIFE next byte is manufacturer specific 68 1 02 VIFE L2 69 71 4 XXXXXXXX Reactive power L2 AA EDEB Page 85 of 137 DELTAplus meter User s Manual Rev Example of the 2m telegram continued all values are hexadecimal Byte Size in bytes Value Description 72 1 84 DIF size 32 bit integer 73 1 80 DIFE Unit 0 74 1 40 DIFE Unit 1 gt xx10 2 75 1 AQ VIF for units var with resolution 0 01var 76 1 FF VIFE next byte is manufacturer specific 77 1 03 VIFE L3 78 80 4 XXXXXXXX Reacti
116. ite access level is set by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 07 L field calculated from C field to last user data 3 1 07 L field repeated 4 1 68 Start character 5 1 53 73 C field SND UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 01 DIF size 8 bit integer 9 1 VIF next byte is manufacturer specific 10 1 6A VIFE write control 11 1 XX Write control 1 Closed 2 Open by password 3 Open 12 1 XX CS checksum calculated from C field to last data 13 1 16 Stop character AA EDEB 105 of 137 DELTAplus meter User s Manual Rev This command is affected by the write protection level set 6 1 4 2 23 Set tariff source In tariff meters with internal clock and no tariff inputs the tariffs are controlled by either the internal clock or via communication The tariff source is set by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 08 L field calculated from C field to last user data 3 1 08 L field repeated 4 1 68 Start character 5 1 53 73 C field SND UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 01 DIF size 8 bit integer 9 1 VIF next byte is manufacturer specific 9 1 9 VIF extension of man
117. ith it no status VIFE will be sent out or 0 will be sent out If the status is data error or no data available the standard M bus status coding values will be sent out 18 hex or 15 hex 01 FF 6F 01 Total power outage OE ED 39 24 19 09 14 03 06 Time date 39 24 09 14 03 06 sec min hour day month year The telegram sent out will be all values are hexadecimal Byte Size in bytes Value Description 1 1 68 Start character 2 1 7E L field calculated from C field to last user data 3 1 7E L field repeated 4 1 68 Start character 5 1 08 C field RSP UD 6 1 XX A field address 7 1 72 Cl field variable data respond LSB first 8 11 4 XXXXXXXX Identification Number 8 BCD digits 12 13 2 4204 Manufacturer ABB 14 1 05 Version 15 1 02 Medium 02 Electricity 16 1 XX Number of accesses 17 1 XX Status 18 19 2 0000 Signature 0000 no encryption 20 1 01 DIF size 1 byte integer 21 1 FF VIF next byte is manufacturer specific 22 1 eF VIFE event type 23 1 XX Event type 30 1 02 DIF size 2 byte integer 31 1 FF VIF next byte is manufacturer specific 32 1 ED VIFE current harmonics 33 1 FF VIF next byte is manufacturer specific 34 1 8x VIFE phase x 35 1 FF VIF next byte is manufacturer specific 36 1 F8 Extension of manufacturer specific vife s next vife s used for numbering 37 1 02 Harmon
118. ity to electromagnetic HF Fields 80 MHz 2 GHz at 10 V m IEC61000 4 3 Immunity to conducted disturbance 150kHz 80MHz IEC 61000 4 6 Radio frequency emission according to CISPR 22 class B Electrostatic discharge ESD 15 kV for IEC 61000 4 2 3 3 OPTIONS 3 3 1 INPUTS Max Wire size 2 5 mm Data for low voltage inputs Voltage range 0 40 V AC DC 0 V to 2 V is interpreted as off 4 5 V to 40 V is interpreted as on Input resistance 8 13 kO Power consumption Less than U U 8000 where U is voltage in volts Minimum pulse length and pause 30 ms Data for high voltage inputs Voltage range 0 276 V AC DC 0 V to 20 V AC DC is interpreted as off Page 48 of 137 DELTAplus meter User s Manual Rev 45 V to 276 V AC DC is interpreted as on Input resistance 80 85 Power consumption Less than U U 80000 where U is voltage in volts Minimum pulse length and pause 30 ms 3 3 2 OUTPUTS Data for low voltage outputs Voltage range 0 40 V DC AC Output resistance 12 25 Q Maximum current 100 mA Data for high voltage outputs Voltage range 0 400 V DC 0 282 V AC Output resistance 30 55 Maximum current 100 mA 3 3 3 INTERNALCLOCK Data for internal clock e Approved according to IEC 62052 11 which contains general requirements for electricity meters and time switches and IEC 62054 21 which contains particular requirements for time switches e Accuracy s
119. l M bus interface except regarding setting of baudrate as the baudrate is fixed to 2400 baud on the optical interface 69 of 137 DELTAplus meter User s Manual Rev 6 1 M BUS The M Bus Meter Bus is a bus system for the remote reading of meters It is a master slave system for communication on twisted pair where all meters are slaves The M bus protocol can also be used on other medias than twisted pair For information regarding M bus see also internet address www m bus com 6 1 1 Register Active Energy Total COMMUNICATION OBJECTS Description Total cumulative Active Energy Active Energy Tariff 1 Cumulative Active Energy Tariff 1 Active Energy Tariff 2 Cumulative Active Energy Tariff 2 Active Energy Tariff 3 Cumulative Active Energy Tariff 3 Active Energy Tariff 4 Cumulative Active Energy Tariff 4 Reactive Energy Total Total cumulative Reactive Energy Reactive Energy Tariff 1 Cumulative Reactive Energy Tariff 1 Reactive Energy Tariff 2 Cumulative Reactive Energy Tariff 2 Reactive Energy Tariff 3 Cumulative Reactive Energy Tariff 3 Reactive Energy Tariff 4 Cumulative Reactive Energy Tariff 4 CT ratio Current transformer ratio VT ratio Voltage transformer ratio Outputs Read and set status of outputs Inputs current state Read current state of input 1 and 2 Inputs stored state Read and reset s
120. le to erase all event log data by sending a special command for details see chapter 6 If the maximum number of events have been stored and new events are stored the oldest events will be overwritten The events are not displayed on the LCD and can only be read via communications For details see chapter 6 No event log data will be stored if date and or time is not set 2 12 6 TARIFF CONTROL BY CLOCK In tariff meters with internal clock the tariffs normally are controlled via the internal clock This is done by programming the meter to activate desired tariff at specific switchpoints in time It is possible to define up to 4 different day types and 4 different seasons with different tariff schemes for each combination of day type and season The day types are defined on a weekly basis and the season switches are defined on a yearly basis PADDED Page 39 of 137 DELTAplus meter User s Manual Rev It is possible to define yearly cyclic dates where a specific day type or season switch is specified It is also possible to define specific dates where a specific day type is specified The active tariff is displayed on the LCD see section 2 6 5 and can also be read via communication If date and or time is not set a programmable default tariff will be active 2 12 7 OUTPUTS CONTROL BY CLOCK In meters with internal clock equipped with outputs the outputs can be controlled via the internal clock This is done by programming the met
121. lid Also directly after startup all harmonics will be marked not available as they haven t been measured yet As the harmonics are measured sequentially one at a time they will be available one by one and after approximately 10 seconds after startup they are normally all available PADDED Page 126 of 137 DELTAplus meter User s Manual Rev The telegram sent out will be all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 73 L field calculated from C field to last user data 3 1 73 L field repeated 4 1 68 Start character 5 1 08 C field RSP_UD 6 1 XX A field address 7 1 72 Cl field variable data respond LSB first 8 11 4 XXXXXXXX Identification Number 8 BCD digits 12 13 2 4204 Manufacturer ABB 14 1 05 Version 15 1 02 Medium 02 Electricity 16 1 XX Number of accesses 17 1 XX Status 18 19 2 0000 Signature 0000 no encryption 20 1 02 DIF size 2 byte integer 21 1 FF VIF next byte is manufacturer specific 22 1 ED VIFE current harmonics 23 1 FF VIF next byte is manufacturer specific 24 1 8x VIFE phase x 25 1 FF VIF next byte is manufacturer specific 26 1 F8 Extension of manufacturer specific vife s next vife s used for numbering 27 1 00 Number 0 signifies total harmonics 28 29 2 XXXX Total harmonics in percent
122. limit is exceeded 2 7 4 SET MODE Set mode is reached by pressing the Set button while being in Normal Alternative or Instrumentation mode For a flowchart on Set mode see figure 2 12 in section 2 7 optional settings are in italic style After reaching Set mode the different set items and its respective setting can be viewed by pressing the scroll button short scroll To activate the change procedure the set button is pressed when the set item to be changed are displayed The hand symbol CF is flashing while the change procedure is active Doing a long scroll while the set operation is pending lets you to exit without altering the setting Escape When all settings have been done the Normal mode is reached by doing a long scroll Below are listed the different settings that can be modfied in Set mode and the change operation procedure 2 7 4 1 Current transformer ratio CT Allows you to set the current transformer ratio only on transformer rated meters The allowable range is 1 9999 When the set button is pressed while the present current transformer ratio is shown in set mode Page 25 of 137 DELTAplus meter User s Manual Rev it becomes possible to change the ratio The hand symbol qu ES is flashing and the first digit in the current transformer ratio is displayed always starts with 0 The first digit is increased by 1 for every press on the scroll but
123. mware version for example 317 for version 3 17 and def is the metrological version for example 100 for version 1 00 that is the part of the firmware handling the basic metrology functions In firmware version below 3 17 only the total firmware version is sent out with 4 characters as Dabc Page 84 of 137 DELTAplus meter User s Manual Rev Example of the 2m telegram all values are hexadecimal Byte Size in bytes Value Description 1 1 68 Start character 2 1 C1 L field calculated from C field to last user data 3 1 C1 L field repeated 4 1 68 Start character 5 1 08 C field RSP_UD 6 1 XX A field address 7 1 72 Cl field variable data respond LSB first 8 11 4 XXXXXXXX Identification Number 8 BCD digits 12 13 2 4204 Manufacturer ABB 14 1 02 Version 15 1 02 Medium 02 Electricity 16 1 XX Number of accesses 17 1 Status 18 19 2 0000 Signature 0000 no encryption 20 1 04 DIF size 32 bit integer 21 1 29 VIF for units W with resolution 0 01W 22 25 4 XXXXXXXX Active power Total 26 1 04 DIF size 32 bit integer 27 1 A9 VIF for units W with resolution 0 01W 28 1 FF VIFE next byte is manufacturer specific 29 1 01 VIFE L1 30 32 4 XXXXXXXX Active power L1 33 1 04 DIF size 32 bit integer 34 1 A9 VIF for units W with resolution 0 01W 35 1 FF VIFE next byte
124. n Alternative Mode 2 7 21 LCD test The first display item in Alternative Mode is a display test where all LCD segments are set see figure 2 6 which displays all LCD segments 2 7 2 2 Error information After the LCD test the installation check errors and internal meter errors are displayed If no errors are detected the text no Err is displayed The error codes are displayed as Err xxx error code xxx The different errors are explained in chapter 4 3 3 2 7 2 3 Energy display in Alternative mode In Alternative mode the energy registers are displayed in kWh kvarh with 1 decimal in direct connected meters see figure below which illustrate the difference between Normal and Alternative mode Alternative mode Fig 2 15 Energy display in Normal Alternative Mode in direct connected meters In transformer rated meters the secondary energy in kWh kvarh with 2 decimals is displayed irrespective of the transformer ratio settings In tariff meters the tariff indicators are used to indicate which tariff energy register that are displayed see section 2 6 5 2 7 2 4 Transformer ratio The transformer ratio settings is displayed in transformer rated meters The total transformer ratio CT VT is displayed as t xxxxxx the current transformer ratio CT as Ct xxxx and the voltage transformer ratio VT as Ut 2 7 2 5 Pulse output frequency The pulse output frequency is
125. n a transformer rated meter if the CT and VT for the external transformers are programmed into the meter For example in a direct connected 3 element meter with estimated maximum voltage and current of 250 V and 65 A and pulse width 100 ms and required pulse pause 30 ms the maximum allowed pulse frequency will be 1000 3600 250 65 3 0 030 0 100 568 impulses kWh Another example In a transformer rated 3 element meter with estimated maximum voltage and current of 63 100 V 6300 V VT ratio 100 and 6 50 A 300 A CT ratio 50 and pulse width 100 ms and required pulse pause 30 ms the maximum allowed pulse frequency will be 1000 3600 6300 300 3 0 030 0 100 6 16 impulses kWh kvarh For technical data on pulse outputs see chapter 3 2 12 INTERNAL CLOCK AND TIME DEPENDANT FUNCTIONS In DELTAplus meters equipped with internal clock the meter keeps track of date and time and are equipped with various time dependant functions such as load profile maximum demand monthly values event log outputs controlled by time and in tariff meters with internal clock the tariffs are normally controlled via the internal clock Below these functions are described Details regarding reading writing of time date and reading of the time dependant functions via communication is given in chapter 6 The internal clock and time dependant functions are not available in meters with internal LON or EIB communication
126. nction can log the following events Overvoltage on each phase Undervoltage level 1 on each phase Undervoltage level 2 on each phase Phase voltage outage Negative power Total power outage Presence of current harmonics For the over and undervoltage events a percentage level with respect to a nominal voltage is given which is programmable The phase voltage outage level use the same level as undervoltage level 2 The negative power event will be logged if abnormal negative power is detected For current harmonics a percentage level for the total harmonic distorsion of the harmonics measured can be set and the event will be logged if that limit is exceeded For the different events there exist a programmable minimum time before the event is registered The overvoltage and undervoltage events use the same minimum time The other event types have their own minimum times For each registered event the start date time and the duration in seconds is stored A total power outage will always end a pending event except for the event total power outage which it will start The number of events to be stored are programmable from 0 up to 512 Note that changing the number of events will erase all load profile data due to the fact that data for this quantity is stored after the event log data in the EEPROM and changing the number of events change the addresses for data aftercoming data and requires reset of the load profile data It is possib
127. nd the VIFE is less than 1111 1000 the next byte is a standard VIFE otherwise it is the first data byte If the extension bit of the manufacturer specific VIFE is set and the VIFE is bigger or equal to 1111 1000 the next byte is an extension of manufacturer specific VIFE s VIF Code Description Range Coding Range E000 Onnn Energy 1o nnn 3 wp 0 001Wh to 10000Wh E010 1nnn Power 3 w 0 001 to 10000W E010 00nn On time duration nn 00 seconds nn 01 minutes nn 10 hours nn 11 days E110 110n Time point n 0 date Data type G n 1 time amp Data type F or date 6 byte bcd coding E111 1000 Fabrication 00000000 to 99999999 E111 1010 Bus Address 0 to 250 1111 1011 Extension of VIF codes Not used by the DELTAplus meter 1111 1101 Extension of VIF codes True VIF is given in the first VIFE and is coded using Table FD 1111 1111 Manufacturer Specific Next VIFE is manufacturer specific Codes for Value Information Field VIF Codes for Value Information Field Extension VIFE used with extension indicator FDh If the VIF contains the extension indicator FDh the true VIF is contained in the first VIFE VIFE Code Description E000 1010 Manufacturer E000 1100 Version E000 1110 Firmware Version E001 0111 Error Flags binar E001 1010 Digital Output binar E001 1011 Digital Input binar E001 1100 Baud rate E010 01 Interval length 00 seconds 01 minutes 10 hours 11 days
128. nge primary time source for internal clock E110 1100 Total power outage time E110 1111 Event type E111 0000 Measurement period E111 1000 Extension of manufacturer specific vife s next vife s used for numbering E111 1001 Extension of manufacturer specific vife s next vife s specifies actual meaning E111 1110 Extension of manufacturer specific vife s next vife s used for manufacturer specific record errors status VIFE Codes for reports of record errors meter to master VIFE Code of Record Error Error Group E000 0000 E001 0101 No data available undefined value E001 1000 Data error Page 77 of 137 DELTAplus meter User s Manual Rev VIFE Codes for object actions master to meter VIFE Code Action Description E000 0111 Set data to zero storage number 2 nd manufacturer specific VIFE followed after VIFE 1111 1000 F8 hex VIFE Code Description Ennn nnnn Used for numbering 0 127 2 nd manufacturer specific VIFE followed after VIFE 1111 1001 F9 hex VIFE Code Description DST day of week day type season Quantity specification of maximum demand Quantity specification of previous values Quantity specification of load profile Quantity specification of event log Tariff source LCD error suppress mask Readout request of input 1 counter load profile profile in format counter register values at end of intervals Readout request of input 1 counter load profile
129. not available is when load profile is cleared in the middle of a day In this case the previous intervals of that day will be marked not available If there is a power fail lasting over a complete day or several days no data will be stored for these days The maximum number of load profile days that can be stored depends on several things Page 37 of 137 DELTAplus meter User s Manual Rev e Interval length Shorter interval length gives less number of maximum days For example changing the interval length from 60 to 30 minutes gives half or half 1 the maximum amount of days that can be stored e Maximum number of monthly values maximum demand values and events to log selected Load profile data monthly values maximum demand values and events are stored in the EEPROM memory and increasing the maximum number of monthly values maximum demand values and events results in less amount of memory available for load profile Number of quantities stored in load profile For example using load profile for 2 quantities instead of 1 gives half or half 1 the maximum amount of days that can be stored It is possible to erase all load profile data values by sending a special command for details see chapter 6 If the maximum number of days have been stored and new values are stored the oldest dayily values will be overwritten If the date is set to another date than the current date the meter will always start a new load profile da
130. nsformer ratios can easily be set by using the two buttons under the sealable cover The energy value s shown in normal mode in the display is the real primary energy consumption Page 7 of 137 DELTAplus meter User s Manual Rev 2 2 METER PARTS The different parts of the meter are depicted below accompanied by a short description of each part 3 Tariff input Inputs 4 Sealable cover Outputs Wiring diagram for Communication Tariff input Option Inputs Outputs 2 Scroll Communication 1 Set 5 Meter type label 6 Sealing tape on the side 15 Sealing points four z t Light sensor 14 Communication window 8 LED 13 LCD 9 Pulse output s or communication 10 Sealable cover Wiring diagram for Meter connections 11 Terminal block Pulse output s 12 Space for ownership and numbering Communication marking Fig 2 1 Meter parts Position 1 Set button Used when programming the meter Position 2 Scroll button Used when viewing different information and when programming the meter Position 3 Terminal for tariff inputs Inputs Outputs Communication As an option the meter can be equipped with tariff inputs or digital inputs outputs or communication capabilities In this case the meter will have terminals mounted in the place indicated in the picture Position 4 and 10 Sealable covers The meter contains 2 sealable covers which cover all the terminals On the
131. of 1 interval in telegram 104 pulses 00 Consumption in 1 st interval 12 pulses C hex 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 68 B8 B8 68 08 00 72 44 47 24 00 42 04 02 02 17 00 00 00 44 ED 6A 00 0C C5 04 01 FD 25 3C CE 40 FD 61 58 02 00 00 00 00 C4 40 FD El 27 OD 00 00 00 C4 40 FD El 27 11 00 00 00 C4 40 FD El 27 11 00 00 00 C4 40 FD El 27 OD 00 00 00 C4 40 FD El 27 OD 00 00 00 C4 40 FD El 27 OD 00 00 00 C4 40 FD El 27 00 00 00 C4 40 FD El 27 OD 00 00 00 C4 40 FD El 27 OD 00 00 00 C4 40 FD El 27 OD 00 00 00 C4 40 FD El 27 OD 00 00 00 C4 40 FD El 27 OD 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 4D 16 AA EP ED PADDED Page 112 of 137 DELTAplus meter User s Manual Rev Readout of 1 day of input 2 load profile register values System sends read request command for input 2 register values 68 OA OA 68 73 FE 51 02 EC FF F9 16 AC OC 76 16 Reading acknowledge E5 Sending request UD2 10 7b fe 79 16 Reading response 68 C5 C5 68 08 00 72 42 10 00 00 42 04 02 02 15 20 00 00 44 ED 24 00 00 AC 0 1 25 3 80 40 FD 61 52 23 00 00 00 00 CE 80 40 FD 61 52 23 00 00 00 00 80 40 FD 61 52 23 00 00 00 00 CE 80 40 FD 61 52 23 00 00 00 00 80 40 61 52 23 00 00 00 00 80 40 61 52 23 00 00 00 00 80 40 61 52 23 00 00 00
132. on level set 94 137 DELTAplus meter User s Manual Rev 6 1 4 2 2 Set primary address The primary address is set either via the buttons or by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 06 L field calculated from C field to last user data 3 1 06 L field repeated 4 1 68 Start character 5 1 53 73 C field SND_UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 01 DIF size 8 bit integer 9 1 7A VIF Bus Address 10 1 XX New primary address 11 1 XX CS checksum calculated from C field to last data 12 1 16 Stop character This command is not affected by the write protection level set 6 1 4 2 3 Change baud rate The baud rate of the electrical M bus interface is set either via the buttons or by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 03 L field calculated from C field to last user data 3 1 03 L field repeated 4 1 68 Start character 5 1 53 73 C field SND_UD 6 1 XX A field address 7 1 Bx Cl field New baud rate 8 1 XX CS checksum calculated from C field to last data 9 1 16 Stop character Note that this command does not affect the baud rate of the optical IR interface which is fixed to 2400 baud This command is not affec
133. onality Page 13 of 137 DELTAplus meter User s Manual Rev STANDARD METERS WITH EIB COMMUNICATION Type JHU Po Basic Measurement Communication Accuracy Voltage Optional functionalit Page 14 of 137 DELTAplus meter User s Manual Rev 2 4 ENERGY INDICATOR COD LED Fig 2 4 Energy indicator The red LED in the middle of the front is an indicator that flashes in proportion to the active energy and can be used when testing and verifying the meter Every pulse means that a certain amount of energy has been registered that is it has a certain pulse frequency This frequency is marked on the nameplate In combined meters measuring both active and reactive energy it s also possible to have the LED flash in proportion to the reactive energy see section 2 7 2 9 for more information 2 5 BUTTONS The DELTAplus meter has two user buttons behind the sealable cover 2 5 1 1 SET BUTTON This is the programming button It is used to reach Set Mode activate a change operation and to confirm a changed setting 2 51 2 SCROLL BUTTON LIGHT SENSOR The scroll button and the light sensor lies functionally in parallel that is pressing the scroll button for a certain amount of time has the same effect as putting light onto the light sensor for the same amount of time The light sensor is placed below the text SCROLL and the torch picture on the front of the meter see pic
134. onfirmed by pressing the SET button which completes the time set operation It is also possible to set time via communication For details see chapter 6 29 of 137 DELTAplus meter User s Manual Rev 2 7 4 8 Date Allows setting of the date When the SET button is pressed while the date day month year is displayed in Set mode 13 th of august year 2007 in figure below The day digits are increased by 1 for every short press possible values 1 31 on the SCROLL button The chosen value is confirmed by pressing the SET button The month digits then starts flashing and is increased for every short press possible values 1 12 on the SCROLL button The chosen value is confirmed by pressing the SET button The year tens digit then starts flashing and is increased for every short press possible values 0 9 on the SCROLL button The chosen value is confirmed by pressing the SET button The year unit digit then starts flashing and is increased at every short press possible values 0 9 on the SCROLL button When the chosen value is confirmed by pressing the SET button the new date is set 30 of 137 DELTAplus meter User s Manual Rev It is also possible to set date via communication For details see chapter 6 2 7 4 9 Communication write acc
135. only bit 2 and 3 in byte which are used If both bits are 1 error display due to loss of date and or time is suppressed 6 1 4 3 Reading data from the meter that require a read request command Page 106 of 137 DELTAplus meter User s Manual Rev Some data in the meter can only be read by first giving a special read request command followed by giving a request user data 2 command The read request command contain in some cases data specifying the date or time date for the required data The data read by this procedure is load profile maximum demand event log and harmonics Monthly values is sent out by a normal M bus readout but can also be read this way Harmonic data can also be sent out in a normal M bus readout but is normally not Below is described the read request commands and the format of the readout data 6 1 4 3 1 Read request and readout of load profile data Read request of load profile is done by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 0A L field calculated from C field to last user data 3 1 0A L field repeated 4 1 68 Start character 5 1 53 73 C field SND UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 02 DIF size 2 byte integer 9 1 EC VIF time point date M bus data type G 10 1 FF VIF next byte is manufacturer specific 11 1 9 VIF extension of manufact
136. or This test is only made on 3 element meters 4 31 3 Power measurement The active power is measured and the sign is checked all DELTAplus meters measure energy in only one direction from utility to customer that is positive energy In 3 element meters the active power sign check is done individually on each phase as well as on the total phase power summed together In 2 element meters only the total power is checked The individual elements are not checked because having negative active power on one element can be a normal case in a 2 element meter when having a highly reactive load power factor angle of more than 60 degrees At the extremes of having a completely capacitive or inductive load the phase angle between voltage and current will be 120 degrees on one element The total active power however should always be positive There is a lower limit of absolute power below which the negative power test is not performed 0 2 W for transformer rated meters and 2 W for direct connected meters This limit works individually for each test individual phases on 3 element meters and the total on all meters The reason for having a lower limit is to not receive erroneous results due to disturbances at very low input signals Thus it is necessary to insure that the power consumed on each phase in 3 element meters and the total on all meters is higher than this low limit when doing the installation check so that the test will be complete
137. or the harmonics measured is calculated according to 4 ED Page 24 of 137 DELTAplus meter User s Manual Rev 9 IY 1 100 n 2 where I is the fundamental current and is the current for harmonic with number At each measurement the harmonic is set to 0 if the rms value of the current is below a certain lower limit Note that as only the harmonics up to 500 Hz is measured and because the harmonics is measured one at a time is not a true total harmonic distorsion which would require that all harmonics up to infinite frequency would be measured and that all harmonics including the fundamental would be measured at the same time Note also that presence of harmonics over 500 Hz will result in folding distorsion as the sampling frequency is 1000 Hz The folding distorsion can affect the measurements below 500 Hz and give erroneous results Due to the possible presence of folding distorsion and the fact that the harmonics is measured sequentially one at a time it is recommended that the harmonic measurement results of the meter is used as a tool to detect presence of harmonics and not as an exact instrument to get very precise results In the event log function of the meter see section Error Reference source not found it is possible to log presence of harmonics A percentage limit for the total harmonic distorsion of the harmonics measured is then set and the start time date and duration will be logged if this
138. ot being correct The imbalance error is usually however rather small typically 0 2 and if the currents are balanced the total error in the energy measurement will be very small as a too small energy measurement on one element will be compensated by approximately opposite errors for the other phases It is also possible to use a 3 element meter with only 2 current transformers see figures below which shows this type of connection with and without the neutral available Note that if the current transformers are connected to protective earth it must be connected in only one point Both methods require a balanced system voltages and currents the same in all 3 phases It shall also be mentioned that having a floating neutral figure 5 10 also can give additional errors in the measured voltages due to impedance unlinearity and imbalance inside the meter PADDED Page 66 of 137 DELTAplus meter User s Manual Rev 3 element transformer rated meter L1 L2 E P1 P2 N Fig 5 13 Using a 3 element meter with 2 current transformers 3 element transformer rated meter 11213145167 89 11 Si S2 L1 P1 P2 L2 EN P1 P2 Fig 5 14 Using a 3 element meter with 2 current transformers and floating neutral Page 67 of 137 DELTAplus meter User s Manual Rev 5 5 SUMMATION It is possible to sum the current from several current transformers into one meter see the example bel
139. ow where 2 loads are summed in a 3 element meter It is of course also possible to use in a single phase or 2 element meter 3 element transformer rated meter To load 1 To load 2 Fig 5 15 Summation of loads 68 of 137 DELTAplus meter User s Manual Rev 6 COMMUNICATION Reading a meter through a communication interface gives a number of advantages compared to manual reading e time it takes to read a number of meters is much shorter This makes it also possible to perform continuous readings The risk of getting wrong values because of mistakes during manual reading is reduced to a minimum e The values are stored electronically which makes it easier to process them further All DELTAplus meters have an optical interface on the left side of the meter For communication via the optical interface the M Bus protocol is used As an option the DELTAplus meter can be equipped with an interface for serial communication Three different types are available M Bus LonWorks and EIB Common for the three interfaces is that they all use twisted pair cable as communication media All meters in a network are individually addressable The number of meters that can be connected in one network depends on the type of system and the installation This chapter describes the M bus and LonWorks communication All protocol information mentioned concerning M bus is valid for both the optical port and the electrica
140. pecified in IEC 62054 21 Time error less than 5 ppm less than 0 5 second error per day at reference temperature 25 degrees centigrade e Backup by super capacitor with backup time more than 2 days Typical backup time at room temperature is 6 days Page 49 of 137 DELTAplus meter User s Manual Rev 4 INSTALLATION WARNING The voltages connected to the DELTAplus meter are dangerous and can be lethal Therefore all voltages must be switched off when installing the DELTAplus meter 4 1 MOUNTING The DELTAplus meter can be mounted in different ways We will guide you through the ways you can mount your DELTAplus meter For some of the mounting modes you need additional accessories for part numbers see chapter 8 4 1 1 DIN RAIL MOUNTED The DELTAplus meter is aimed to be mounted on a DIN rail designed according to the standard DIN 50022 In this case no extra accessories are needed and the meter is fastened on the rail so that the black plastic snap piece on the back of the meter snaps onto the rail 4 1 2 WALL MOUNTED The recommended way to mount the meter on a wall is to mount a separate DIN rail see picture below on the wall and mount the meter on this SO Fig 4 1 DIN rail used for wall mounting When the DELTAplus meter is wall mounted a long cover is sometimes needed see figure below Fig 4 2 Long cover 50 of 137 DELTAplus meter User s Manual Rev 4
141. phase angle between voltage and current is 25 84 degrees and an inductive load with power factor 0 45 on phase 3 phase angle between voltage and current is 63 26 degrees If the phase voltages are U1 230 V U2 228 V and U3 227 V and the phase currents are 1128 A 2 23 A and 18 15 A the total power will be Ptot P1 2 230 8 228 23 0 9 227 15 0 45 1472 00 4719 60 1532 25 7723 85 W PADDED Page 65 of 137 DELTAplus meter User s Manual Rev Fig 5 11 Vector diagram for 3 element meter with an unbalanced load Sometimes it is desired to use a 3 element meter without having the neutral connected see fig 5 7 below It can be done with both transformer rated and direct connected meters 3 element transformer rated meter Fig 5 12 3 element measurement without neutral connected This can for example be desired in cases where a voltage transformer without a neutral is being used for the moment but where a change to a voltage transformer with neutral will be made sometime in the future To save the trouble of changing the meter at that time a 3 element meter is used from the beginning Using a 3 element meter without having the neutral connected will decrease the accuracy due to the fact that the floating neutral connection on the meter terminal 11 will lie at a different level than the true neutral N because of impedance imbalance inside the meter resulting in the phase voltages n
142. profile function each day is divided into intervals with a certain length where the energy consumption in each interval is stored The possible interval lengths are 15 30 or 60 minutes and is programmable The quantities that can be stored are active and reactive energy and number of pulses registered on input 1 and 2 Storage of reactive energy is only possible on combined meters and storing of pulses requires meters with corresponding input Which quantities to be stored is programmable All quantities use the same interval length Note that changing the interval length or the quantities to be stored will erase all load profile data The load profile function always use normal time irrespective if daylight savings time is active or not Each load profile data value are associated with a status value The status value gives information such as e Interval is longer or shorter than defined length deviation limit in seconds is programmable Power outage occured during interval Data overflow Data not available Data error Intervals which have not been passed yet or that haven t been passed through regular time flow will be marked not available This will for example happen if the time is changed forward over a number of intervals If for example the time is changed forward from 11 23 43 to 14 13 55 and 60 minute intervals is used the 2 intervals between 12 00 to 14 00 will be marked not available Another case where intervals will be marked
143. r bits 5 8 11 1 8x DIFE storage number bits 9 12 12 1 Ox DIFE storage number bits 13 16 13 1 ED VIF time date 14 1 FF VIF next byte is manufacturer specific 15 1 F9 VIF extension of manufacturer specific vife s next vife specifies actual meaning 16 1 1A VIFE specifies event log 17 18 6 XXXXXXXXXXXX Time date sec min hour day month year 19 1 XX CS checksum calculated from C field to last data 20 1 16 Stop character When sending the read request a readout reference date and time is specified in the data 6 byte bcd see table above and an event offset is specified in the storage number The sign of the offset is specified in the unit bit in the first DIFE If the offset is negative the meter will send out events from the specified event and backwards in time If it the offset is 1 the meter will start sending out events from the 1 st event that have date time stamp before the specified date time If it the offset is 2 the meter will start sending out events from the 2 nd event that have date time stamp before the specified date time etc If the offset is zero or positive the meter will send out events from the specified event and forward in time If it the offset is 0 the meter will start sending out events from the 1 st event that have date time stamp after the specified date time If it the offset is 1 the meter will start sending out events from the 2 nd event that have date time stamp after the specified date time etc The data will
144. rd EEPROM for storing energy 1 total and 4 tariff registers for both active and reactive delivered energy historic values load profile monthly values event log etc calibration and initialization values for the microcontroler and for meter specific values which are used by the firmware in the microcontroller The data retention time for stored data in the EEPROM is more than 40 years e Acommunications interface for connection to an internal communication board Aninfra red communications interface consisting of a phototransistor and a LED for connection to an external communication unit A quartz crystal controlled real time clock used to keep track of date time The real time clock uses a super capacitor as backup source at power outages 2 13 2 INPUT OUTPUT BOARDS The DELTAplus meter can be equipped with different options with input s and or output s The following basic configurations exist 1 input 2 inputs 1 input and 1 output 1 output 2 outputs The principal schematics are depicted in figures below All inputs and outputs are galvanically isolated from the rest of the meter electronics by optocouplers Page 42 of 137 DELTAplus meter User s Manual Rev Microcontroller Input 1 16 Interface and p Input 15 protection circuitry e 3 Fig 2 19 Block diagram for 2 inputs Microcontroller Output 2 16 Output 1 Common
145. rmally 5 of the basic current Note that as only the harmonics up to 500 Hz is measured and because the harmonics is measured one at atime it is not the true total harmonic distorsion that is calculated Measuring the true total harmonic distorsion require that all harmonics up to infinite frequency is measured and that all harmonics including the fundamental would be measured at the same time Note also that presence of harmonics over 500 Hz will result in folding distorsion as the sampling frequency is 1000 Hz and that the folding distorsion can affect the harmonic measurements below 500 Hz Due to the possible presence of folding distorsion and the fact that the harmonics is measured sequentially one at a time it is recommended that the harmonic measurement results of the meter is used as a tool to detect presence of harmonics and not as an exact instrument to get very precise results In the event log function of the meter see section 2 12 5 it is possible to log presence of harmonics A percentage limit for the total harmonic distorsion measured is then set and the start time date and duration will be logged if this limit is exceeded 2 9 INPUTS AND OUTPUTS As an option the meter can be equipped with inputs and or outputs Either 1 or 2 inputs or outputs or 1 input and 1 output The inputs outputs are built with optocouplers and are galvanically isolated from all other meter electronics The inputs consists beside of the optoco
146. rs lies between 200 201 If any of the internal errors occur the meter functionality cannot be guaranteed and the meter shall be taken out of service For more information regarding the installation check and installation errors see chapter 4 3 2 6 4 7 SEGMENT 7 CHARACTERS AND UNIT All values such as energy power voltage and current etc are displayed by using the 7 segment 7 characters and the unit segments There are also 2 decimal points to enable display of values with 1 or 2 decimals The figure below shows an example where the active energy without a decimals with unit kWh and the reactive total power with 1 decimal and unit var is displayed Fig 2 9 Display of active energy and reactive power 2 6 5 INDICATION OF ACTIVE TARIFF Fig 2 10 Tariff indicators Active tariff is indicated with a constant flashing of the tariff indicator for example T1 for tariff 1 When a value for a tariff which is not active is displayed its indicator remains lit The only time when the active tariff is not blinking is when a total energy register is displayed or an LCD test is pending all segments on 2 6 6 LOAD INDICATOR Fig 2 11 Load indicator There are three arrows which will rotate as soon as the current is above the start current level in at least one of the measuring elements The rotating speed is constant and independent of the measured energy If the metering is below the s
147. s lt 80A e Transformer rated meters also often called CT meter for currents gt 80A using external current transformers CT s with secondary current x 6A and optionally external voltage transformers VT s Both groups are divided into subgroups One or three phase connection Active energy measurement Combined energy measurement both active and reactive Tariff controlled meters Meters equipped with communication option Meters equipped with clock Meters equipped with inputs and or outputs 9 of 137 DELTAplus meter User s Manual Rev The meter type is reflected on the front label see figure below ABB id Customization Symbol for Type designation number information network type Voltage DAB 13007 3 57 280 100 500 Rated and maximum current and accuracy class 16 Cl B CI 1 Prog Imp kWh Pulse output frequency 2CMA139305R1000 LED 5000 Imp kWh 0 LED frequency 0402 2003 33 1 Serial number time Operating temperature safety MID Weare Protective class 11 manufacture rene verification notified body id Fig 2 2 Meter type label Note that the nominal voltage spans over a range 57 to 288 V AC from phase to neutral and 100 to 500 V AC from phase to phase A meter is identified with its type designation For explanation of the positions in the type designation see further down in this chapter 2 31 NETWORK
148. s measured with current transformers through which the current to measure flows The output current from the transformer flows through load resistors to produce voltages which via multiplexer and amplifier are fed to the microcontroller The mains voltage is divided by resistor dividers and fed into the microcontroller 2 push buttons called scroll and set to control the display on the LCD and for programming of transformer ratios pulse output frequency etc The scroll button is in most cases used to display the next quantity or item in a sequence whereas the set button is used for programming the meter e An oscillator that clocks the microcontroller A3 phase wide voltage range power supply that generate 5V for feeding the electronics microcontroller EEPROM etc e A voltage reference used by the microcontroller A D converters that is the reference for all current and voltage samples LED light emitting diode that flashes with a certain energy pulse frequency imp kWh phototransistor which that lies functionally in parallel with the scroll button Putting a short flash of light on the phototransistor for example with a torch causes the same action as pressing the scroll button A plastic light pipe leads down to the phototransistor mounted on the board e 1 or 2 optoisolated pulse outputs which give a certain amount of pulses per kWh kvarh e Aninterface which can be connected to an input output boa
149. s media The LonWorks interface in the DELTAplus meter consists of a separate PCB with a Neuron and an FTT 10A transceiver for communication on twisted pair The transmission of data between the meter and the interface board is performed via internal communication The interface board reads the meter cyclically The reading interval is normally 30 seconds and can be changed via the network variable ncilnternalUpdT 6 2 1 TECHNICAL DATA ADDITIONS TO THE BASIC METER Operating and display elements Service LED and pin Network interface FTT 10A Communication speed 78 kbps A software clock is implemented in the LonWorks interface This clock is based on a timer in the Neuron It takes leap years but not summer winter time changes into account The clock will run approximately 2 seconds too fast or slow per 24 hours There is no back up for the clock and it is cleared if power fails 6 2 1 1 Communication objects Node Object Register Network variable name Description nviRequest Supports RQ NORMAL RQ UPDATE STATUS and RQ REPORT MASK nvoStatus Time nviTimeSet nvoTime Set date and time in the software clock Date and time from the software clock Node State nvoNodeState BitO Master status bit If any other bit is set this bit is also set Biti Any application error Bit2 Power low Bit3 Permanent error Bit4 Temporary error Bit5 Installation
150. s meter User s Manual Rev Meter sends out data telegram 7E 68 7E FF BE B ptr HANA BE B pt Ooocooooooooooco NO pi Hj N 04 20 6F 39 70 6F 39 70 6F 3 9 70 6F 39 18 6F 39 18 68 0A 46 00 09 46 00 08 46 00 07 54 00 06 54 00 08 00 72 42 10 00 00 42 04 02 02 07 00 00 00 Data header Undervoltage on phase 3 level 1 24 15 13 03 06 Time date 46 24 15 13 03 06 sec min hour day month year 00 00 Duration 112 seconds Undervoltage on phase 2 level 1 24 15 13 03 06 00 00 Undervoltage on phase 1 level 1 24 15 13 03 06 00 00 Overvoltage on phase 3 22 15 13 03 06 00 00 Overvoltage on phase 2 22 15 13 03 06 00 00 gt More events exist 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 E6 16 System sends out request UD2 FE 59 16 10 5B Meter sends out data telegram 68 7E 7E 68 6F 05 OE ED 39 54 04 20 18 00 FF 6F O1 OE ED 39 45 04 20 03 00 Ef 15 OE ED B9 15 04 AO 15 00 FF EF 15 OE ED B9 15 04 AO 15 00 FF EF 15 OE ED B9 15 04 AO 15 00 08 00 72 42 10 00 00 42 04 02 02 08 00 00 00 Overvoltage on phase 1 22 15 13 03 06 00 00 Total power outage 22 15 13 03 06 00 00 00 Status VIFE 15 gt No data available 00 00 00 00 00 00 00 00
151. se system 5 3 3 PHASE 2 ELEMENT METERING The 2 element metering method also called two watt meter method is used in systems with 3 wires normally a 3 phase system that does not have a neutral conductor see example in figure below where a direct connected 2 element meter is measuring the active energy E consumed by a load A 2 element meter can be used irrespectively of the load being balanced or not E frm U 2 t 1101 U3 t U 2 t I3 1 Fig 5 6 2 element measurement In a 2 element meter the L2 voltage is used as the voltage reference and the voltage difference between that voltage and the L1 and L3 voltage are measured and multiplied by its respective current The active energy consumed by the load is the product of momentary voltages U1 U2 and U3 U2 and the currents 11 and 2 integrated over the desired measuring time period see mathematical formula above in the picture In the case where no harmonics are present and the rms values of the voltages and currents are constant the total active power can be expressed as Ptot P1 U1 U2 x I1 x cos 12 U3 U2 x I3 x cos 932 where 12 is the phase angle between the U1 U2 voltage and the 11 current and 32 is the phase angle between the U3 U2 voltage and the I3 current This is illustrated below in a vector diagram which depicts the vectors for the phase voltages U1 U2 the phase currents 11 12 I3 and the Page 61 of 137
152. size 4 digit BCD 172 1 FF VIF next byte is manufacturer specific 173 1 59 VIFE Frequency with resolution 0 01Hz 174 175 2 XXXX Frequency 176 1 1F DIF more records will follow in next telegram 177 197 21 000000000000000 PAD bytes 000000000000000 000000000000 198 1 XX CS checksum calculated from C field to last data 199 1 16 Stop character AA EDEB PADDED Page 87 of 137 DELTAplus meter User s Manual Rev Example of the 3 telegram values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 D4 L field calculated from C field to last user data 3 1 D4 L field repeated 4 1 68 Start character 5 1 08 C field RSP_UD 6 1 A field address 7 1 72 Cl field variable data respond LSB first 8 11 4 XXXXXXXX Identification Number 8 BCD digits 12 13 2 4204 Manufacturer ABB 14 1 02 Version 15 1 02 Medium 02 Electricity 16 1 Number of accesses 17 1 XX Status 18 19 2 0000 Signature 0000 no encryption 20 1 02 DIF size 4 digit BCD 21 1 FF VIF next byte is manufacturer specific 22 1 60 VIFE power factor with resolution 0 001 23 24 2 XXXX Power factor Total 25 1 02 DIF size 16 bit integer 26 1 FF VIF next byte is manufacturer specific 27 1 EO VIFE power factor with resolution 0 001 28 1 FF VIFE next byte is manufacturer specific 29 1
153. splayed sequentially and automatically one at a time Normally each quantity is being displayed for 6 seconds When the last quantity has been displayed it will start all over again displaying the first quantity If the scroll button is pressed shortly it s possible to single step and view a quantity for longer time All meters will be in Normal Mode after power up Normal mode will always be reached after some time if no buttons are pressed as the meter automatically steps back until it reaches Norma Mode The Normal Mode can only be interrupted by entering the Set Mode or the Alternative Mode Below is described the format for the energy display in Normal Mode 19 137 DELTAplus meter User s Manual Rev 2 7 1 1 Energy display in Normal mode In Normal Mode the energy registers are displayed in kWh kvarh without decimals in direct connected meters In tariff meters the tariff indicators are used to indicate which tariff energy register that are displayed see section 2 6 5 see example in figure below where the tariff 2 active energy register is displayed T1 is blinking indicating that tariff 1 is the currently active tariff Fig 2 13 Normal Mode energy display in direct connected meter In all transformer rated meters set to secondary metering CT VT 1 the energy is displayed in kWh kvarh with 1 decimal in Normal Mode At primary metering CT VT gt
154. ss B Electrostatic discharge ESD 15 kV for IEC 61000 4 2 3 2 TRANSFORMER RATED METER 3 21 VOLTAGE INPUTS Nominal voltage 3 x 57 288 100 500 V 4 wire 3 element 3 x 100 500 V 3 wire 2 element 1 x 57 288 V Single phase Voltage range 20 to 15 of nominal voltage Power dissipation Less than 1 VA 1 W per phase Terminal wire area 0 5 6 Recommended tightening torque 2 Nm 3 2 CURRENT INPUTS Rated current 1 A Reference current 1 A Maximum current 6 A Transitional current 0 05 A Minimum current 0 02 A Starting current 2 mA Power dissipation lt I k VA on all inputs where is current in amperes and is less than 0 002 Terminal wire area 0 5 10 mm Recommended tightening torque 2 Nm 3 2 3 GENERAL DATA Frequency 50 60 Hz 5 Accuracy According to IEC 62053 21 Cl 1 for active energy According to IEC 62053 23 Cl 2 for reactive energy Display of energy LCD with 7 digits height 7 mm 3 2 4 MECHANICAL DATA AND TESTS Material Polycarbonate in transparent front glass bottom case upper case and terminal cover Glass reinforced polycarbonate in terminal block Protection class 11 Glow wire test according to IEC 695 2 1 Dust and water protection acc to IEC 60529 protection class IP51 mounted in protective enclosure IP20 on terminal block without protective enclosure Weight 0 304 kg Page 47 of 137 DELTAplus meter User s Manual Rev 3 2 5 ENVIR
155. t is identified by its start character 10h and consists of five characters Besides the C and A fields it includes the check sum and the stop character 16h e Long Frame The Long Frame format is identified by its start character 68h and consists of a variable number of characters After the start character the L field is transmitted twice then the start character once again followed by the C A and Cl fields The user data 0 252 bytes is transmitted after the Cl field followed by the check sum and the stop character 16h Page 72 of 137 DELTAplus meter User s Manual Rev 6 1 3 1 1 Field descriptions All fields used in the telegram frames have a length of one byte 8 bits Length Field L field The L field gives the quantity of the user data inputs plus 3 for the C A and Cl fields It is transmitted twice in telegrams using the long frame format Control Field C field The C field contains information of the direction of the data flow error handling and Besides labeling the functions and the actions caused by them the control field specifies the direction of data flow and is responsible for various additional tasks in both the calling and replying directions To the meter Su 2 z From the meter PRM 0 0 F2 Coding of the EE Fa e primary message bit PRM is used to specify the direction of data flow It is set to 1 when a telegram is sent from a master
156. t standard incorporated in all meters are pointed out in the manual as options WARNING The voltages connected to the DELTAplus meter are dangerous and can be lethal Therefore it must be insured that the terminals are not touched during operation When installing the DELTAplus meter all voltages must be switched off 6 137 DELTAplus meter User s Manual Rev 2 PRODUCT DESCRIPTION This chapter contains a description of the basic functions and practical handling of the DELTAplus meter Functionality regarding communication is described in chapter 6 2 1 FAMILY OVERVIEW The DELTAplus meter is a product family consisting of a broad range of electronic electricity meters primarily used for DIN rail mounting in a closed environment The meter exists in 2 basic types one direct connected meter which is aimed to be connected directly to the mains supply and one transformer rated meter aimed to be connected via external current transformers and optionally voltage transformers All DELTAplus meters follow ABB s pro M standard which defines mechanical dimensions way of mounting 35 mm DIN rail and design outlook All DELTAplus meters are type approved according to international electricity meter IEC standards All meter types are approved according to IEC 62052 11 which contains general requirements for electricity meters and IEC 62053 21 which contains particular requirements for active electricity energ
157. tart current level all the arrows are constant and not rotating If the total active energy is positive the arrows is rotating in the forward direction and if the total active energy is negative the arrows is rotating backwards If the total energy is negative the energy registers will stand still 18 of 137 DELTAplus meter User s Manual Rev 2 7 DISPLAY MODES The DELTAplus meter display system is divided into different display modes Normal Alternative and Instrumentation Mode They are distinguished from each other by the small triangle at the bottom middle of the LCD which is off in Normal Mode continuously on in Alternative Mode and flashing in Instrumentation Mode There is also a Set Mode where different programmable settings can be modified Some information are always displayed on the LCD irrespective of active mode Below in the figure are depicted the display system with its different modes and the different information displayed Always displayed Connected phases Load indication CT VT ratio used indication Active tariff not at total energy display Error status 1 Instrumentation mode 1 7 Active power for each element Alternative mode i i LCD test wv 1 Error codes 1 Active energy consumption tariff i 1 1 1 Reactive energy consumption tariff 1 1 1 1 Total active energy and per tariff Total reactive energy and per tariff
158. te is manufacturer specific 66 1 F8 Extension of manufacturer specific vife s next vife s used for numbering 67 1 05 Harmonic number 68 69 2 XXXX 5 th harmonic in percent with 1 decimal 70 1 02 DIF size 2 byte integer 71 1 FF VIF next byte is manufacturer specific 72 1 ED VIFE current harmonics 73 1 FF VIF next byte is manufacturer specific 74 1 8x VIFE phase x 75 1 FF VIF next byte is manufacturer specific 76 1 F8 Extension of manufacturer specific vife s next vife s used for numbering 77 1 05 Harmonic number 78 79 2 XXXX 5 th harmonic in percent with 1 decimal 80 1 02 DIF size 2 byte integer 81 1 FF VIF next byte is manufacturer specific 82 1 ED VIFE current harmonics 83 1 FF VIF next byte is manufacturer specific 84 1 8x VIFE phase x 85 1 FF VIF next byte is manufacturer specific 86 1 F8 Extension of manufacturer specific vife s next vife s used for numbering 87 1 05 Harmonic number 88 89 2 XXXX 5 th harmonic in percent with 1 decimal 90 1 02 DIF size 2 byte integer 91 1 FF VIF next byte is manufacturer specific 92 1 ED VIFE current harmonics 93 1 FF VIF next byte is manufacturer specific 94 1 8x VIFE phase x 95 1 FF VIF next byte is manufacturer specific 96 1 F8 Extension of manufacturer specific vife s next vife s used for numbering 97 1 05 Harmonic number 98 99 2 XXXX 5 th harmonic in percent with 1 decimal 100 1 02 DIF size 2 byte integer 101 1 FF VIF next byte is manufacturer specific 10
159. ted by the write protection level set 6 1 4 2 4 Reset power fail counter The power fail counter is reset to 0 by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 07 L field calculated from C field to last user data 3 1 07 L field repeated 4 1 68 Start character 5 1 53 73 C field SND UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 00 DIF size no data 9 1 FF VIF next byte is manufacturer specific 10 1 98 VIFE no of power fails 11 1 07 VIFE clear 12 1 XX CS checksum calculated from C field to last data 13 1 16 Stop character This command is not affected by the write protection level set Page 95 of 137 DELTAplus meter User s Manual Rev 6 1 4 2 5 Set current transformer CT ratio The current transformer ratio CT is set by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 08 L field calculated from C field to last user data 3 1 08 L field repeated 4 1 68 Start character 5 1 53 73 C field SND UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 0 DIF size 4 digit BCD 9 1 FF VIF next byte is manufacturer specific 10 1 68 VIFE CT ratio 11 12 2 XX XX New CT ratio 13 1 XX CS checksum calculated from C field to last data 14
160. tem sends out request UD2 10 5b fe 59 16 Meter sends out data telegram 68 73 73 68 08 00 72 00 00 00 00 42 04 05 02 ad 00 00 00 02 ff ed ff 82 ff 8 00 85 00 02 ff ed ff 82 ff 8 02 02 00 02 ff ed ff 82 ff f8 03 62 129 of 137 DELTAplus meter User s Manual Rev 00 ff ff 08 00 System sends out request UD2 02 8 ed 00 00 ff 05 ff 00 00 ed 5b 82 02 00 ff 00 ff ff 00 10 7b fe 79 16 82 02 8 ed 00 ff ff 07 ff 00 8 ed 02 82 d4 Meter sends out data telegram 68 00 ff 00 ff ff 08 00 Readout of harmonic data starting from phase 2 System sends harmonic data read request command 73 00 83 02 8 ed 02 00 73 00 ff ff 05 ff 00 00 68 02 8 ed 04 83 02 00 08 ff 02 ff 00 ff ff 00 00 ed 00 83 02 8 ed 00 72 ff 00 ff ff 07 ff 00 00 83 02 8 ed 01 83 4b 04 ff 00 ff 16 00 Ff 04 00 16 04 82 02 8 00 8 ed 02 83 02 8 00 ff ff 09 00 00 ff 00 ff ff 09 02 8 ed 04 42 60 83 02 8 ed 03 ff 06 ff 00 04 00 ff ff 06 ff 00 ed 01 82 1 05 02 8 ed 00 83 Of ff 00 ff 00 02 ff 03 ff 00 ff 00 82 02 8 00 de ed 60 83 02 8 00 Page 130 of 137 DELTAplus meter User s Manual Rev 6 1 4 4 Error Information flags 7 8 Eeprom Crc error Hardware error Date not set T
161. ton The chosen value is confirmed by pressing the set button The same procedure is then done for the other digits If the transformer ratio set was bigger than 1 primary metering the primary metering symbol L will be on Note that the allowable maximum total transformer ratio CT VT is 999 999 2 7 4 2 Voltage transformer ratio VT Allows you to set the voltage transformer ratio only on transformer rated meters The allowable range is 1 9999 When the set button is pressed while the present voltage transformer ratio is shown in set mode it becomes possible to change the ratio The hand symbol Er is flashing and the first digit in the voltage transformer ratio is displayed always starts with 0 The first digit is increased by 1 for every press on the scroll button The chosen value is confirmed by pressing the set button The same procedure is then done for the other digits If the transformer ratio set was bigger than 1 primary metering the primary metering symbol will be on Note that the allowable maximum total transformer ratio CT VT is 999 999 2 7 4 3 Pulse output frequency Allows you to set the pulse output frequency only on meters with pulse output s The frequency is selected from a list The pulse output s are primary which means that the CT and VT ratio are considered see information regarding pulse outputs in section 2 11 When the set button is presse
162. tor 0 95 Note that on a 2 element meter the power on one element can even be negative This is the case for example for a balanced inductive load with power factor less than 0 5 For a balanced inductive load with power factor 0 45 phase angle between voltage and current on each phase is arccos 0 45 63 3 degrees phase voltages 225 V and phase currents 15 A the power on the 2 elements will be P1 225 43 15 cos 93 3 336 5 W and 225 JB 15 cos 33 3 4885 9 W and the total power Ptot 336 5 4885 9 4549 4 W 2 element metering can also be used in a 4 wire system under condition that the current in the neutral connection is zero Using it ina system having a non zero neutral current will decrease the accuracy but can sometimes be justified if the current is small compared to the line currents or if high accuracy is not required It is also possible to use this method measuring only one current see figure below This method will only give correct result in a balanced system Note that the current flows backwards through phase 1 and 3 and that the phase voltages not are connected to the normal inputs when the current transformer is connected to phase 1 and 3 Page 63 of 137 DELTAplus meter User s Manual Rev 2 element transformer rated meter 2 element transformer rated meter Fig 5 9 2 element measurement with only 1 current transformer 64 137 DELTApl
163. torage temperature range 40 to 70 Humidity 7596 yearly average 9596 on 30 days year Resistance to heat and fire Terminal 960 C cover 650 C IEC 60695 2 1 3 1 5 PULSE OUTPUT STANDARD ON ALL METERS EXCEPT LON MBUS Current 0 100 mA Voltage 0 247 V AC 350 V DC polarity independent Terminal wire area 0 2 5 except combined meters 0 0 5 mm Pulse output freq Programmable Pulse width 100 ms as standard Recommended tightening torque 0 5 Nm 3 1 6 VISIBLE PULSE INDICATOR Red LED with frequency 1000 imp kWh Pulse width 40 ms AA EP ED PADDED Page 46 of 137 DELTAplus meter User s Manual Rev 3 1 7 STANDARDS IEC 62052 11 IEC 62053 21 class 1 amp 2 IEC 62053 23 class 2 IEC 62054 21 Measurement instrument directive MID category A amp B electrical environmental class E2 and electrical environmental class M2 EN 50470 1 EN 50470 3 category A amp B Pulse output according to IEC 62053 31 SO DIN 43864 3 18 ELECTROMAGNETIC COMPATIBILITY EMC AND INSULATION PROPERTIES According to IEC 62052 11 IEC 62053 21 and IEC 62053 23 Impulse voltage test 6 kV 1 2 50us IEC 600 60 Surge voltage test 4 kV 1 2 50us 61000 4 5 Fast transient burst test 4 kV IEC 61000 4 4 Immunity to electromagnetic HF Fields 80 MHz 2 GHz at 10 V m IEC61000 4 3 Immunity to conducted disturbance 150kHz 80MHz IEC 61000 4 6 Radio frequency emission according to CISPR 22 cla
164. tored state of input 1 and 2 Inputs counter Read and clear input pulse counter 1 and 2 Pulse frequency Read the pulse frequency Current L1 Instantaneous current in the L1 phase Current L2 Instantaneous current in the L2 phase Current L3 Instantaneous current in the L3 phase Voltage L1 N Instantaneous voltage between L1 and neutral Voltage L2 N Instantaneous voltage between L2 and neutral Voltage L3 N Instantaneous voltage between L3 and neutral Voltage L1 L2 Instantaneous voltage between L1 and L2 Voltage L2 L3 Instantaneous voltage between L3 and L2 Active Power Total Instantaneous total active power Active Power L1 Instantaneous active power in L1 Active Power L2 Instantaneous active power in L2 Active Power L3 Instantaneous active power in L3 Reactive Power Total Instantaneous total reactive power Reactive Power L1 Instantaneous reactive power in L1 Reactive Power L2 Instantaneous reactive power in L2 Reactive Power L3 Instantaneous reactive power in L3 Apparent Power Total Instantaneous total apparent power Apparent Power L1 Instantaneous apparent power in L1 Apparent Power L2 Instantaneous apparent power in L2 Apparent Power L3 Instantaneous apparent power in L3 Phase angle voltage L1 Instantaneous phase angle voltage for L1 voltage L1 is reference Phase angle volta
165. total active quadrant is displayed in the format Lt X where X is the active quadrant number 0 4 for example Lt 1 if the total load is in quadrant 1 inductive load Zero is presented if the load is zero For definition of the different quadrants see section 5 1 2 7 3 6 Frequency The frequency is measured in hertz with 2 decimals and displayed in the format Fr for example Fr 50 03 2 7 3 7 Current harmonics The total current harmonic distorsion of the harmonics measured is displayed in percent with 1 decimal in the format dx XXX X where x is the phase number 1 3 999 9 will be displayed if the harmonic is bigger than 999 9 96 The separate harmonics is displayed in percent with 1 decimal in the format dxy XX X where x is the phase number 1 3 and y is the harmonic number 2 9 99 9 will be displayed if the harmonic is bigger than 99 9 96 The separate harmonic frequencies measured is multiples of the fundamental frequency normally around 50 or 60 Hz up to the 9 th harmonic but not higher than 500 Hz At 60 Hz for example the 9 th harmonic will have frequency 540 Hz and will then not be measured If the harmonic have not been measured dxy is displayed The current harmonics 2 9 together with the fundamantal is measured sequentially one at a time approximately 1 harmonic each second Each harmonic is calculated according to I I 10096 and the total current harmonic distorsion f
166. ture below When the meter is sealed only the light sensor can be used In the text below only the scroll button is mentioned but everything said is also applicable to the light sensor P SCROLL CO Fig 2 5 Light sensor With the scroll button the information displayed can be changed such as going to different display modes or proceeding to the next quantity No settings can be altered by this button The scroll button has two different functions depending for how long time it is pressed Short scroll When the scroll button is pressed for up to two seconds it displays the next value This can be used if you don t want to wait for the next quantity to be displayed or you can enter single step mode to view a value for longer time Long scroll When the scroll button is pressed for between 2 and 10 seconds it executes an Escape see below When a long scroll is performed in Normal Mode the DELTAplus meter switches to Alternative Mode When a long scroll is performed in Alternative Mode the DELTAplus meter switches to nstrumentation Mode Notes The activity starts when the button is released AA 41 PADDED Page 15 of 137 DELTAplus meter User s Manual Rev Do not press more than one button at a time A long scroll in Set Mode lets you step back Escape This can be used for example to exit a pending set operation without altering the setting There is always a time out of two minutes default If a
167. ufacturer specific vife s next vife specifies actual meaning 10 1 06 VIFE tariff source 11 1 XX Tariff source 0 Internal clock 1 Communication command 12 1 XX CS checksum calculated from C field to last data 13 1 16 Stop character This command is affected by the write protection level set This command only have effect in meters with internal clock where the tariffs can be controlled either from the internal clock or by command via communication 6 1 4 2 24 Suppress LCD error display Suppress of error indication on LCD can be done by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 OF L field calculated from C field to last user data 3 1 OF L field repeated 4 1 68 Start character 5 1 53 73 C field SND_UD 6 1 XX A field address 7 1 51 Cl field data send LSB first 8 1 07 DIF size 8 byte integer 9 1 FF VIF next byte is manufacturer specific 10 1 9 VIF extension of manufacturer specific vife s next vife specifies actual meaning 11 1 07 VIFE time source 12 19 1 XXXXXXXXXXXXXXXX Suppress data LSB byte first If bit 2 and 3 in databyte 0 are 1 display of error at date time fail is suppressed else it is not suppressed 20 1 XX CS checksum calculated from C field to last data 21 1 16 Stop character This command is affected by the write protection level set Note that it is
168. ufacturer specific vife s next vife s used for numbering 97 1 05 Harmonic number 98 99 2 XXXX 5 th harmonic in percent with 1 decimal 100 1 02 DIF size 2 byte integer 101 1 FF VIF next byte is manufacturer specific 102 1 ED VIFE current harmonics 103 1 FF VIF next byte is manufacturer specific 104 1 8x VIFE phase x 105 1 FF VIF next byte is manufacturer specific 106 1 F8 Extension of manufacturer specific vife s next vife s used for numbering 107 1 05 Harmonic number 108 109 2 XXXX 5 th harmonic in percent with 1 decimal 110 1 1F DIF more records will follow in next telegram 111 119 9 000000000000000 PAD bytes 000 120 1 XX CS checksum calculated from C field to last data 121 1 16 Stop character EP ED 128 of 137 DELTAplus meter User s Manual Rev It is also possible to send a read request where a specific phase is specified by sending the following command all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 08 L field calculated from C field to last user data 3 1 08 L field repeated 4 1 68 Start character 5 1 53 73 C field SND_UD 6 1 A field address 7 1 51 Cl field data send LSB first 8 1 01 DIF size 8 bit integer 9 1 VIF next byte is manufacturer specific 10 1 9 VIF extension of manufacturer specific vife s next vife specifies actual meaning 11 1 1B VIFE specifies
169. uplers of interface protection circuitry towards the outside world The microcontroller inside the meter reads the status of the inputs via the optocouplers 2 versions exist for the input and input output boards one for low voltages and one for high voltages The versions with only outputs handle both low and high voltages All types handle both DC and AC voltage polarity independent An input that is not connected left floating is the same as having voltage off The outputs are built with with solid state MOSFET optocouplers with polarity independent outputs The equivalent circuitry of the outputs is an ideal relay in series with a resistor For technical data regarding inputs outputs see chapter 3 2 9 1 FUNCTIONALITY OF INPUTS The inputs count pulses register activity and current status This data can be read via the communications bus or read on the LCD Inputs can also function as as tariff inputs to control the active tariff see section 2 10 The input counters and activity status are saved at a power failure and restored at power up The 2 input counter registers are displayed with 7 digits maximum value 9 999 999 The unit which is displayed factory setting is normally r as in rotations or revolutions for input counter 1 and rh for input counter 2 The current input status is displayed as InP1 X and InP2 X where X is or 1 1 means voltage applied to input Input activity stored status is displayed as
170. urer specific vife s next vife specifies actual meaning 12 1 VIFE specifies data requested 10 Active energy register values at end of interval 11 Active energy consumption per interval 12 Reactive energy register values at end of interval 13 Reactive energy consumption per interval 14 Input 1 register values at end of interval 15 Input 1 number of counts per interval 16 Input 2 register values at end of interval 17 Input 2 number of counts per interval 13 14 2 XXXX Date M bus data type Isb byte sent first 15 1 XX CS checksum calculated from C field to last data 16 1 16 Stop character When sending the read request the readout quantity is specified in the last VIFE and the requested date is specified in the data The format for the date is M bus data type G which consist of 2 bytes coded according to the following Day in bits 0 4 Valid values 1 31 Month in bits 8 11 Valid values 1 12 Year in bits 5 7 and bits 12 15 bit 5 7 is the Isb bits Valid values 0 99 Example 23 rd september 2006 23 9 06 will be coded as bit 15 0 0000 1001 1101 0111 in binary format which will be 09D7 in hexadecimal format If load profile data for the specified date is stored in the meter it will send out data for that day If no data is stored in the meter for the specified date it will send out data from the nearest date backwards in time Therefore the system should check the date sent out in the telegram to verify that it is t
171. us 04 total power outage occured during interval BS BDA GS NS eS M rs S 4E 04 98 23 00 00 00 00 4E 84 FF FE 01 17 25 00 00 00 00 Register value 25 17 kWh manufacturer specific status 01 interval long 4E 04 39 26 00 00 00 00 lF Dif 1F gt Exist more load profile data 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 bytes 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 ED 16 Checksum and stop byte System sends out request UD2 10 5B FE 59 16 Meter sends out data telegram 68 Al Al 68 08 00 72 44 47 24 00 42 04 02 02 17 00 00 00 Data header 44 ED 6B 00 OD C5 04 Date and time for first register value in telegram end of 1 st interval 01 FD 25 3 Interval length 60 minutes 4E 84 FF FE 02 14 27 00 00 00 00 Register value 27 14 kWh manufacturer specific status 02 interval short PADDED Page 109 of 137 DELTAplus meter User s Manual Rev 04 35 28 00 00 00 00 04 53 29 00 00 00 00 04 50 30 00 00 00 00 84 FF FE 04 49 31 00 00 00 00 84 FF FE 06 59 32 00 00 00 00 Register value 32 59 kWh manufacturer specific status 06 power outage occured during interval and interval short Ed Ed Ed 15 BS S WWW Ez 04 53 33 00 00 00 00 04 51 34 00 00 00 00 04 68 35 00 00 00 00 04 36 36 00 00 00 00 04 55 37 00 00 00 00 04 74 38 00 00 00 00 Hj Er Ed Dd Ed Edd EH 00
172. us meter User s Manual Rev 5 4 3 PHASE 3 ELEMENT METERING The three watt meter method is normally used in three phase systems having a neutral conductor see example in figure below where a direct connected 3 element meter is measuring the active energy E consumed by a load E eII U 12 U 3 t 13 dt Fig 5 10 3 element measurement In a 3 element meter the neutral voltage is used as the voltage reference and the voltage difference between the neutral voltage and the L1 L2 and L3 voltages are measured and multiplied by its respective current The active energy consumed by the load is the product of momentary voltages U1 U2 and and the currents 11 12 and 13 integrated over the desired measuring time period see mathematical formula above in the picture In the case where no harmonics are present and the rms values of the voltages and currents are constant the total active power can be expressed as Ptot P1 P2 U1 e 1 e cos 1 U2 12 e cos 2 U3 I3 cos 3 where 1 2 and is the phase angles between the phase voltage and its respective current This is illustrated below in a vector diagram which depicts the vectors for the phase voltages U1 U2 U3 and the phase currents I1 I2 I3 for an unbalanced load with a capacitive load with power factor 0 8 on phase 1 phase angle between voltage and current 36 87 degrees an inductive load with power factor 0 9 on phase 2
173. valid telegram not necessarily with its own address on the new baud rate within 30 seconds it changes back to the old baud rate This is done to prevent a meter to be unreachable in an installation where the network makes it impossible to communicate on the new baud rate The baud rate can also be changed via the buttons The read write settings commands for load profile monthly values maximum demand event log and miscellaneous user configurable settings are not described in this manual as special programs supplied by ABB exist that handle these settings 81 of 137 DELTAplus meter User s Manual Rev 6 1 4 1 Examples of telegram 1 4 readouts Example of the 1 telegram all values are hexadecimal Byte No Size in bytes Value Description 1 1 68 Start character 2 1 C5 L field calculated from C field to last user data 3 1 C5 L field repeated 4 1 68 Start character 5 1 08 C field RSP_UD 6 1 XX A field address 7 1 72 Cl field variable data respond LSB first 8 11 4 XXXXXXXX Identification Number 8 BCD digits 12 13 2 4204 Manufacturer ABB 14 1 02 Version 15 1 02 Medium 02 Electricity 16 1 XX Number of accesses 17 1 Status 18 19 2 0000 Signature 0000 no encryption 20 1 OE DIF size 12 digit BCD 21 1 04 VIF for units kWh with resolution 0 01kWh 22 27 6 XXXXXXXXXXXX Acti
174. ve Tini Tin2 Off on gt Tariff 2 active Tini Tin2 on on gt Tariff 2 active Note With the above coding it s enough to use only input Tin or Tno the other input can be left floating 2 11 PULSE OUTPUTS The DELTAplus meter is normally equipped with one pulse output for active energy with terminals numbered 20 and 21 The meter sends out a certain amount of pulses per kilowatt hour Combined meters measure both active and reactive energy normally have 2 pulse outputs one for the active and one for the reactive energy with terminals numbered 20 21 and 22 21 is the common terminal 20 the active and 22 the reactive terminal The pulse outputs are primary which means that the pulses are sent out in proportion to the true primary energy For transformer rated meters this is done by using the current and voltage transformer ratios CT and VT ratio programmed into the meter For direct connected meters there are no external transformers used and the amount of pulses sent out are in proportion to the energy flowed through the meter The pulse outputs are galvanically isolated from the rest of the electronics in the meter They fulfil and supersede the German DIN 43 864 standard often called SO and the IEC standard 62053 31 The outputs have a maximum voltage and current specified to 247 Volt 350 V DC 100 mA They are built with MOSFET optocouplers with polarity independent outputs The equivalent circuitry of the
175. ve energy Total 28 1 8b DIF size 12 digit BCD 29 1 10 DIFE tariff 1 30 1 04 VIF for units kWh with resolution 0 01kWh 31 36 6 Active energy Tariff 1 37 1 8E DIF size 12 digit BCD 38 1 20 DIFE tariff 2 39 1 04 VIF for units kWh with resolution 0 01kWh 40 45 6 XXXXXXXXXXXX Active energy Tariff 2 46 1 8b DIF size 12 digit BCD 47 1 BO DIFE tariff 3 48 1 00 DIFE 49 1 04 VIF for units kWh with resolution 0 01kWh 50 55 6 XXXXXXXXXXXX Active energy Tariff 3 56 1 8b DIF size 12 digit BCD 57 1 80 DIFE 58 1 10 DIFE tariff 4 59 1 04 VIF for units kWh with resolution 0 01kWh 60 65 6 XXXXXXXXXXXX Active energy Tariff 4 66 1 8E DIF size 12 digit BCD 67 1 80 DIFE 68 1 40 DIFE unit 2 69 1 04 VIF for units kvarh with resolution 0 01kvarh 70 75 6 XXXXXXXXXXXX Reactive energy Total 76 1 8b DIF size 12 digit BCD 77 1 90 DIFE tariff 1 78 1 40 DIFE unit 2 79 1 04 VIF for units kvarh with resolution 0 01kvarh 80 85 6 XXXXXXXXXXXX Reactive energy Tariff 1 86 1 8b DIF size 12 digit BCD 87 1 DIFE tariff 2 88 1 40 DIFE unit 2 89 1 04 VIF for units kvarh with resolution 0 01kvarh 90 95 6 XXXXXXXXXXXX Reactive energy Tariff 2 AA EDEB PADDED Page 82 of 137 DELTAplus meter User s Manual Rev Example of the 1 telegram continued all values are hexadecimal Byte No Size in bytes
176. ve power L3 81 1 84 DIF size 32 bit integer 82 1 CO DIFE Unit 1 83 1 40 DIFE Unit 1 gt xx11 3 84 1 A9 VIF for units VA with resolution 0 01VA 85 87 4 XXXXXXXX Apparent power Total 88 1 84 DIF size 32 bit integer 89 1 CO DIFE Unit 1 90 1 40 DIFE Unit 1 gt xx11 3 91 1 A9 VIF for units VA with resolution 0 01VA 92 1 FF VIFE next byte is manufacturer specific 93 1 01 VIFE L1 94 96 4 XXXXXXXX Apparent power L1 97 1 84 DIF size 32 bit integer 98 1 DIFE Unit 1 99 1 40 DIFE Unit 1 gt xx11 3 100 1 AQ VIF for units VA with resolution 0 01VA 101 1 FF VIFE next byte is manufacturer specific 102 1 02 VIFE L2 103 105 4 XXXXXXXX Apparent power L2 106 1 84 DIF size 32 bit integer 107 1 DIFE Unit 1 168 1 40 DIFE Unit 1 gt xx11 3 109 1 AQ VIF for units VA with resolution 0 01VA 110 1 FF VIFE next byte is manufacturer specific 111 1 03 L3 112 114 4 XXXXXXXX Apparent power L3 115 1 0A DIF size 4 digit BCD 116 1 FD VIF extension of VIF codes 117 1 C8 VIFE for units V with resolution 0 1V 118 1 FF VIFE next byte is manufacturer specific 119 1 01 VIFE L1 120 121 2 XXXX Voltage L1 122 1 0A DIF size 4 digit BCD 123 1 FD VIF extension of VIF codes 124 1 C8 VIFE for units V with resolution 0 1V 125 1 FF VIFE next byte is manufacturer specific 126 1 02 VIFE L2 127 128 2 XXXX Voltage L2 129 1 0A DIF size 4 digit BCD 130 1 FD VIF extension of VIF codes 131 1 C8 VIF
177. w where the voltage and current phasor diagram is depicted for a pure resistive inductive and capacitive load As a result inductive and capacitive loads can be used to compensate each other AA EP ED 58 of 137 DELTAplus meter User s Manual Rev Clockwise rotation Clockwise rotation Resistive load Inductive load Capacitive load Fig 5 1 Vector diagram for resistive inductive and capacitive load A load that consumes both reactive and active energy can be divided into active and reactive components The angle between the apparent power U lI vector and the active power component is described as phase displacement angle or power factor angle often referred to as see figure below Cos is referred to as the power factor Active power U 1 cos unit W Reactive power Q 1 cos unit var Apparent power S unit VA Reactive power Apparent power Active power Fig 5 2 Vector diagram for load with both active and reactive component The type of load can be represented geometrically by 4 power quadrants see figure below 59 of 137 DELTAplus meter User s Manual Rev Export of active power Import of active power Import of reactive power Export of reactive power Fig 5 3 The 4 power quadrants In quadrant 1 the load is inductive and active and reactive energy is imported energy delivery from utility to customer In qu
178. wer or Pt 15 78 kVa for the total apparent power 2 7 8 2 Voltage The format of the voltage displayed depends on the magnitude The table below shows the format for different magnitudes PADDED Page 23 of 137 DELTAplus meter User s Manual Rev Voltage kV Voltage format displayed U lt 1 Volt with 1 decimal 1 lt U lt 10 Volt no decimal 10 lt U lt 100 kV with 2 decimals 100 U 1000 kV with 1 decimal U 2 1000 kV no decimal The voltage is displayed for each element in the format Ux XXX X unit with x being the element number for example U1 230 4 V 2 7 3 8 Current The format of the current displayed depends on the magnitude The table below shows the format for different magnitudes Current Amperes Current format displayed 1 lt 100 Amperes with 2 decimals 100 lt I lt 1000 Amperes with 1 decimal 1000 lt I lt 10000 Amperes no decimal 1000 lt lt 10000 Amperes no decimal 12 10 000 with 2 decimals The current is displayed in the format Ax XX XX unit for example A3 22 93 for a current of 22 93 Amperes on phase 3 2 7 3 4 Power factor Power factor is displayed with 2 decimals in the format Pfx X XX where x is the element number 1 3 or t for the total power for example Pft 0 44 Normally only the total power factor is displayed For definition of the different quadrants see section 5 1 2 7 3 5 Active quadrant In combined meters the
179. wer outage time Read and reset total power outage time Current tariff Read and set current tariff Manufacturer Manufacturer information FW version Firmware version Error flags Read error flags Date and time Read and set date and time Monthly values Read monthly values Load profile Read load profile data Event log Read event log data Maximum demand Read maximum demand data 6 1 2 PHYSICAL INTERFACE The physical interface allows serial half duplex asynchronous communication Since the bus has a master slave structure where there must and can be only one master the meters cannot communicate with each other 6 1 2 1 Optical interface The DELTAplus meter has an optical interface located on the left side Physical characteristics of the interface correspond to the standard IEC 61107 Communication speed is 2400 bps 6 1 2 2 Optional board As an option the DELTAplus meter can be equipped with an electrical M Bus interface The board fulfils the M bus standard specification with the following electrical characteristics Bus voltage Maximum permanent bus voltage Minimum permanent bus voltage Operating bus voltage 12 42V Receive conditions Space USpace Mark UMark gt USpace 10V Maximum space state time 50ms Maximum space state duty cycle Transmit conditions Definition unit load UL Current consumption at mark state IMark
180. with corresponding input All quantities use the same interval length In tariff meters the maximum demand is stored for each tariff for the energies If the time is changed backwards risk of longer interval than specified the pending interval calculations are ended and a new interval calculations are started The same thing happens at a total power failure If there is a power fail lasting over one complete month or months no data will be stored for these month s The maximum number of maximum demand values to be stored are programmable from 0 up to 31 Note that changing the number of maximum demand values will erase all maximum demand data It will also erase all load profile and event log data due to the fact that data for these quantities are stored after maximum demand values in the EEPROM and changing the number of maximum demand values change the addresses for data aftercoming data and requires reset of this data It is possible to erase all maximum demand data by sending a special command for details see chapter 6 Ak 1 Page 38 of 137 DELTAplus meter User s Manual Rev If the maximum number of values have been stored and new values are stored the oldest values will be overwritten The maximum demand values are not displayed on the LCD and can only be read via communications For details see chapter 6 No maximum demand data will be stored if date and or time is not set 2 12 5 EVENT LOG The event log fu
181. ximum given above 19 th of may 2006 01 00 00 hour minute second 94 21 29 30 10 01 00 8E 01 ED 6B 33 59 02 19 05 06 94 31 29 30 10 01 00 8E 01 ED 6B 25 59 03 22 05 06 94 81 10 29 80 02 00 8E 01 ED 6B 00 00 05 24 05 06 94 91 40 29 70 15 02 00 8E 01 ED 6B 00 00 01 19 05 06 94 A1 40 29 42 00 00 8E 01 ED 6B 33 59 02 19 05 06 94 B1 40 29 EO 42 00 00 8E 01 ED 6B 25 59 03 22 05 06 94 81 50 29 A4 00 00 8E 01 ED 6B 00 00 05 24 05 06 94 41 FD 61 00 00 00 00 8E 01 ED 6B 00 00 00 00 00 00 94 81 40 FD 61 00 00 00 00 8E 01 ED 6B 00 00 00 00 00 00 8E 01 ED EB FF 70 00 00 00 01 06 06 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 117 of 137 DELTAplus meter User s Manual Rev 77 16 6 1 4 3 3 Read request and readout of monthly values Monthly values is sent out in a normal readout sequence with start on the 4 th telegram with the most recently stored values having storage number 1 then the 2 nd most recently stored values with storage number 2 in the 5 th telegram etc until the oldest set of monthly values have been sent out ended with the DIF OF to indicate the last telegram It is however also possible to read monthly values with start from a specific date and backwards in time by sending a read request Read request of monthly values is done by sending the following command all values are hexadecimal Byte No
182. y meters Depending on functionality the meters can also be type approved to other standards Combined meters which also measure reactive electricity energy are approved according to IEC 62053 23 which contains particular requirements for reactive electricity energy meters Meter types which have a built in clock are approved according to IEC 62054 21 which contains particular requirements for time switches These standards cover technical aspects regarding climatic conditions electrical requirements electromagnetic compatibility EMC accuracy and some mechanical requirements The meter is equipped with an easy to read liquid crystal display LCD which displays all the important information With the use of two buttons under the sealable cover and a light sensitive sensor handled by a small torch additional information can be viewed The DELTAplus meter normally has a polarity independent solid state semiconductor relay which generates pulses proportional to the measured energy and a red light emitting diode LED on the front which flashes in proportion to measured energy All DELTAplus meters have an infra red communication port on the left side using the Meter bus M bus protocol Optionally the meter can also be equipped with a 2 wire electrical bus The different alternatives that exists are M Bus LonWorks and EIB When the DELTAplus meter is used with external voltage transformers VT s and current transformers CT s the tra
183. y record Therefore when adjusting time it should be avoided to change backwards into the previous date which will then start a new load profile day record Note also that as load profile always uses the normal time changing the time backwards from 01 xx xx to 00 xx xx when daylight savings time is active will mean that normal time will change backwards into the previous date and start a new load profile day record The load profile values are not displayed on the LCD and can only be read via communications For details see chapter 6 No load profile data will be stored if date and or time is not set 2 12 4 MAXIMUM DEMAND In the maximum demand function the time is divided into intervals with a certain length and the mean power in each interval is measured and the maximum mean value is stored together with a date time stamp The possible interval lengths are 15 30 or 60 minutes and is programmable A set of maximum demand values are calculated and stored for each month It is however also possible to start a new period at any time by sending a special freeze maximum demand command via communication for details see chapter 6 For each set of maximum demand values the end date time of the period is stored The quantities that can be stored are active and reactive power and number of pulses registered on input 1 and 2 pulses interval Storage of reactive max demand is only done on combined meters and storing of pulses requires meters
184. yte is manufacturer specific 109 1 CA VIFE phase angle current with resolution 0 1 110 1 FF VIFE next byte is manufacturer specific 111 1 03 VIFE L3 112 113 2 XXXX Phase angle current L3 114 1 01 DIF size 8 bit integer 115 1 FF VIF next byte is manufacturer specific 116 1 17 VIFE current quadrant 117 1 XX Current quadrant total 118 1 01 DIF size 8 bit integer 119 1 FF VIF next byte is manufacturer specific 120 1 97 VIFE current quadrant 121 1 FF VIF next byte is manufacturer specific 122 1 01 VIFE L1 123 1 XX Current quadrant L1 EP Page 89 of 137 DELTAplus meter User s Manual Rev Example of the 3 telegram continued all values are hexadecimal Byte No Size in bytes Value Description 124 1 01 DIF size 8 bit integer 125 1 FF VIF next byte is manufacturer specific 126 1 97 VIFE current quadrant 127 1 FF VIF next byte is manufacturer specific 128 1 02 VIFE L2 129 1 XX Current quadrant L2 130 1 01 DIF size 8 bit integer 131 1 FF VIF next byte is manufacturer specific 132 1 97 VIFE current quadrant 133 1 FF VIF next byte is manufacturer specific 134 1 03 VIFE L3 135 1 XX Current quadrant L3 136 1 81 DIF size 8 bit integer 137 1 40 DIFE Unit 1 138 1 FD VIF extension of VIF codes 139 1 1B VIFE digital input 140 1 XX Input 1 current state 141 1 81

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