Mx38y

Energy Measurement and Management

MT381 Three-phase electronic meters with PLC communication, GSM/GPRS modem and M-Bus communication interface

Technical Description

EAD 020.615.416

Vesion 1.00, 01.07.2011

Mx38y_Technical_Description_DEWA_V1.00.doc 2

Mx38y Single- and three-phase electronic meters with built-in DLC modem, GSM/GPRS modem or RS485 comm. interface

Content:

Revision history ....................................................3 1. MT381 Three-phase electronic meter 4 2. MT381 meter properties.......................4 3. MT381 meter characteristics................6

3.1. MT381 meter appearance............................6 3.2. Meter case (MT381) .....................................6 3.3. Overall and fixing dimensions (MT381)........7 3.4. Metering system (MT381) ............................8 3.5. Meter configuration (MT381)........................9

4. Mx38y meter components ....................9 4.1. Power supply unit .........................................9 4.2. Microcontroller with FRAM memory .............9 4.3. Real-time clock (RTC)..................................9 4.4. Liquid Crystal Display LCD .....................10

4.4.1. Signal flags on LCD.............................10 4.4.2. Tariff on display ...................................11 4.4.3. Console display format ........................11 4.4.4. Data display .........................................11 4.4.5. Scalers.................................................11

Table 2: Data for LCD display............................12 Table 3: display error codes ..............................12

4.4.6. Display of standard messages on meter LCD display and P1..............................12

4.5. LED.............................................................12 4.6. Push-buttons and param-lock ....................12

4.6.1. Reset push-button ...............................13 4.6.2. Scroll push-button................................13 4.6.3. Auto scroll ............................................13 4.6.4. Global meter reset (only for testing

purposes in laboratory).........................13 4.6.5. Manual scroll........................................14 4.6.6. Menu navigation ..................................14

4.7. Communication ports and channels...........15 4.7.1. Optical port P0 - IR communication

interface ................................................16 4.7.2. Port P1 - RJ11 Interface ......................16 4.7.3. M-Bus communication interface (P2) ..17 4.7.4. Communication profiles (P3) ...............19

4.8. Inputs and outputs (option) ........................21 4.8.1. Terminal functions ...............................21 4.8.2. I/O control ............................................21 4.8.3. Alarm inputs.........................................21 4.8.4. Load control and Service control output

..............................................................21 4.8.5. MOS_FET output service .................22 4.8.6. Input/output status ...............................22

4.9. Switching device.........................................22 5. Meter functions....................................23

5.1. Activity calendar and TOU registration.......24 5.2. Internal clock ..............................................28 5.3. Energy and power measurement and

registration ...............................................28 5.3.1. Energy .................................................29 5.3.2. Demand ...............................................29 5.3.3. Maximum (power) demand

measurement........................................31 5.4. Billing profile recorder.................................31

5.4.1. Billing ...................................................32 5.4.1.1. End of billing period ..........................33

5.5. Load-profile (LP) recorder.......................... 33 5.5.1. Meter profile status.............................. 34

5.6. Counters .................................................... 34 5.7. Energy and power limitation, demand and

current supervision .................................. 34 5.7.1. Disconnect control............................... 35

5.8. Errors and event logs................................. 36 5.8.1. Events ................................................. 36 5.8.2. Errors................................................... 36 5.8.3. Alarms ................................................. 38 5.8.4. Long power failure eevent log ............ 41

5.9. Power quality supervision .......................... 41 5.9.1. Voiltage sag......................................... 42 5.9.2. Voiltage swell ...................................... 42 5.9.3. Voltage cut .......................................... 42 5.9.4. Daily peak and minimum..................... 42 5.9.5. Voltage asymmetry.............................. 42 5.9.6. Neutral break detection ....................... 43 5.9.7. Power failure ....................................... 43

5.10. Identification numbers.............................. 43 5.10.1. Meter software identification - software

architecture........................................... 44 5.11. Security .................................................... 44

5.11.1. Access Security................................. 44 5.11.2. Low level Security (LLS) ................... 45 5.11.3. Message Security.............................. 45 5.11.4. Encryption and decryption................. 45 5.11.5. Security policy setup ......................... 45 5.11.6. High level security (HLS)................... 46 5.11.7. Tamper detection .............................. 48

5.12. Prepayment functionality ......................... 48 5.12.1. Payment mode .................................. 48 5.12.2. Credit transfer.................................... 48 5.12.3. Prepayment accounting .................... 48 5.12.4. Token credit....................................... 49 5.12.5. Emergency credit .............................. 49 5.12.6. Consumption based tariff charging ... 49 5.12.7. Time-based auxiliary charging .......... 49

6. Limitation............................................. 50 6.1. Supervision monitor ................................... 50 6.2. Limiter ........................................................ 50

7. Firmware upgrade............................... 50 8. Sequences ........................................... 51 9. Additional meter functions ................ 51 10. Readout via built-in communication

interface ............................................... 52 11. Meter connection procedure ............. 52 12. Accessory for meters managing....... 53 13. Meter maintaining ............................... 53 14. Anti-fraud protection .......................... 53

14.1. Position of the seals................................. 53 14.2. Wire seals ................................................ 53

15. Meter connection ................................ 54 15.1. Meter connection of MT38y meters ......... 54 15.2. Meter Input/Output terminals ................... 54

16. Technical data ..................................... 55 16.1. Terminal data ........................................... 56

17. Type designation ................................ 58



Revision history

Version Date Comment 1.01 15.09.2010 Corrected new

English version 1.02 22.11.2010 Corrected

version 1.03 01.07.2011 DEWA

requirements for MT381



1. MT381 Three-phase electronic meter The MT381 three-phase electronic meter is designed for measuring and registration of active, reactive and apparent energy in single phase two wire or three-phase four-wire network for direct and indirect connection. Measuring and technical characteristics of meter comply with the IEC 62052-11 and IEC 62053-21 international standards for electronic active energy meters, class 1 or 2 (MID, class B or A) , and with IEC 62053-23 standards for reactive energy meters, classes 2 or 3, as well as with IEC 62052-21 standard for time switches.

Measuring and technical characteristics of the meter also comply with the MID standards: EN 504701 (Electricity metering equipment - General requirements, tests and test conditions - Metering equipment: class indexes A, B and C) and EN 504703 (Electricity metering equipment - Particular requirements - Static meters for active energy: class indexes A, B and C).

Meter is designed and manufactured in compliance with the standards and ISO 9001 as well as more severe Iskraemeco standards.

The MT381 meter is a member of the fourth generation of Iskraemeco electronic three-phase meters for a deregulated market of electric power, with the following common functional properties:

Time-of-use (TOU) measurement of active energy and maximum demand (up to 8 tariffs, 12 seasons, 12 weekly programes, 16 masks, 16 switches),

Load-profile registration, Billing registration, LCD display in compliance with the VDEW

specification, with two modes of data display, Internal real-time clock,

Two push-buttons: Reset and Scroll, Optical port in compliance with the IEC 62056-

21 standard for local meter programming and data transfer,

Built-in interface (IR) and a modem (PLC) for remote two way communication, meter programming and data transfer,

M-Bus multi-utility communication (option) P1 serial port for customers OSM (Other

Service Module) module, Plug-in switching device, Limitation of supplied energy, power or current

(option), Remote disconnection / reconnection of energy

supply to individual customers

Prepayment functionality

The MT381 meter utilizes the DLMS communication protocol in compliance with the IEC 62056-46 standard and IEC 62056-21, mode C protocol.

The MT381 meter supports some more functionalities, such as:

Detectors of the meter and the terminal cover opening and tamper magnetic field,

M-Bus for communication with other meters (heat, gas, water)

Frequency measurement Unexpected consumption alarming Code red limitation Prepayment

2. MT381 meter properties Measurement of energy and power (demand)

Meter sums energies (powers) of particular phase as vectors, so it works according to Ferraris principle and at poliphase measurement it arithmetically sums particular phase energies.

Active energy and demand meter Accuracy class 1 or 2

Reactive energy meter Accuracy class 2 or 3

Apparent energy meter

Modes of energy measurement and registration For one-way energy flow direction, three-phase

energy is algebraic sum of energies registered in each of the phases meters are equipped with an electronic reverse running stop.

For two-way energy flow direction, three-phase energy is algebraic sum of energies registered in each of the phases.

For two-way energy flow direction, three-phase energy is sum of absolute values of energies registered in each of the phases.

Meter connection to network The three-phase meter can function as a single-phase or a two-phase meter.

Meter quality: Due to high accuracy and long-term stability of

metering elements no meter re-calibration over its life is required.

High meter reliability. High immunity to EMC.

Time-of-use registration (TOU - up to 8 tariffs): Tariffs change-over according to internal real-

time clock.



Load-profile recorder: Two load-profile recorders (i.e. daily and hourly

values)

Billing-profile recorder: Two billing-profile recorders (each with up to 4

billing times)

Communication channels: Infrared optical port in compliance with the IEC

62056-21 for local data downloading and meter programming

Built-in DLC modem Built-in M-Bus communication interface Built-in RJ11 communication interface (one

way) Built-in P1 communication interface

LCD display: In compliance with the VDEW specification

Two Data display modes: Automatic cyclic data display with display time

of 10 sec. Manual data display mode (by pressing the

Scroll push-button)

Indicators: on LCD:

- Presence of phase voltages L1, L2, L3 - Phase currents flow direction - Actual tariff indication - Status of switching device - Meter status and alarms - 3-state GSM signal level indicator

LED1: Imp / kWh LED2: Imp / kVArh or imp/kVAh

Communication protocols: Optical port: IEC 62056 21, mode C or DLMS

(in compliance with IEC 62056 46) DLC modem: DLMS by IEC 6205646 (PLC

network management) Identification system: IEC 62056 61 COSEM organization of data: IEC 62056-53 M-Bus: EN 13757-2 and EN 13757-3 IEC 61334-5-511 CIASE system P1 port: protocol based on

NEN-EN-IEC 62056-21 Mode D

OBIS data identification code: IEC 6205661

Auxiliary inputs / outputs: Output for load control with a 6 A relay Output for load control with an Optomos relay

Alarm inputs (high voltage) M-Bus interface to which up to 4 gas, heat or

water meters can be connected Active switching device outputs (switching device

ZO350)

Automatic configuration of an AMR system: Meters are registered automatically into an

AMR system (Intelligent Network Management)

Additional meter functions: Detection of phase and voltage unbalance Measurement and registration of under- and

over-voltage Generation of alarms and their transmition:

via the DLC modem and low voltage network: alarm pull at Mx381 the concentrator reads Alarm ON status and Alarm OFF status registers from the meter

Automatic meter setting into the repeater mode (DLC repeater) : Each meter can automatically enter into the

repeater mode and transmit data in both directions, even with meters with which it can not communicate directly.

Data transmission between max. 7 distant meters which temporarily operate in the repeater mode increases efficiency of communication and effective distance between the meters and a data concentrator.

Programming: Programming of the meter as well as Firmware

upgrade can be done locally (via an optical port) or remotely (via GSM modem) in compliance with the predefined security levels.

Detection of meter and terminal cover opening and tamper magnetic field

Simple and fast meter installation

Current terminals: Make good contact with current conductors

irrespective of their design and material Do not damage conductors

Voltage terminals: Internal and/or external connection A sliding bridge (for simple separation of

voltage part from current part)

Compact plastic meter case:



Made of high quality self-extinguishable UV stabilized material that can be recycled

IP54 protection against dust and water penetration (by IEC 60529)

3. MT381 meter characteristics

3.1. MT381 meter appearance

Fig. 1: MT38y meter constituent parts

1. LCD display 8. Terminal cover 2. Technical data 9. Project number 3. Coupling circuit 10. Meter BAR code 4. Legend of registers displayed on LCD 11. Impulse LEDs

5. Meter cover sealing screws

12. Meter technical data

6. Meter serial number 13. Scroll and Reset push-buttons 7. Terminal cover sealing screws

Two screws for fixing the meter cover (item 5) are sealed with metrological seals.

Two screws for fixing the terminal cover (item 7) and the Reset push-button lid are sealed with seals of electric utility.

3.2. Meter case (MT381) A compact meter case consists of a meter base with a terminal block and fixing elements for mounting the meter, a meter cover and a terminal cover. The case is made of self-extinguishing UV stabilized polycarbonate which can be recycled. The case

ensures double insulation and IP54 (IEC 60529) protection level against dust and water penetration.

The top hanger is provided on the back side of the meter base, under the top edge. On request, an extended top hanger can be mounted on the meter base, which ensures the upper fixing hole height of 230 mm above the line connecting the bottom fixing holes (DIN 43857).

The meter cover is made of transparent polycarbonate. A nickel-plated iron ring in the right top corner is utilized for attaching an optical probe to the optical port. There is a lid which is fixed to the meter cover with a hinge. The lid covers the Reset push-button and can be sealed in the closed position.

A terminal block complies with the DIN 43857 standard. It is made of high quality polycarbonate assuring resistance to high temperatures, voltage-breakdown and assures mechanical strength.

Fig. 2: Terminal block of MT381 meter bottom view

1. Current terminals 4. Detector of opening a terminal cover

2. Auxiliary terminals 3. Additional voltage terminals 6. Alarm inputs

7. Port P1

Current terminals are made of zinc-plated iron and have only one screw. A universal clamping terminals assure the same quality of the contact irrespective of the shape of the connection conductor (a compact wire, a stranded wire, greater or smaller cross-sections). They also assure faster meter assembly. Current terminals for currents of up to 120 A have 9.5 mm hole diameter.

The meter can be equipped with max. four additional voltage terminals - 2 (L1), 5 (L2), 8 (L3) and 11 (N). They enable simple connection of additional external devices. They can be connected to current terminals directly or through sliding voltage bridges.

Up to 6 auxiliary terminals can be fitted on the right side of the current terminals. There are connected M-

1

2

3

4

5

6

7

8

5

13

12

11

10 9

7



Bus and relay control outputs. Besides to the optomos relay a 6 A bistable relay for load control can be built into the meter. Outputs: - optomos relay (250 V, 100 mA) - bistable relay (250 V, 6 A).

Detectors (switches) of the terminal cover and the meter cover opening (on the PCB next to the optical port) are built into the meter. Terminal block detector triggers an event that lets you know if and when terminal block cover or meter cover were opened.

Fig 3: Terminal cover opening switch

A sliding voltage bridge is intended for fast and simple separation of meter current and voltage circuits, used for calibration or accuracy testing. A special slider is built in each phase of the connection terminal. It can be shifted up and down with a screwdriver.

Fig.4: Terminal block

Fig.5: Sliding voltage bridge

Fig.6: Auxiliary terminals

Position 0 upper position: When a voltage bridge is in 0 position, it means that the voltage part is separated from the current part. During the meter testing and calibration the sliding voltage bridges should be in position 0.

Position 1 lower position: When a voltage bridge is in position 1, the voltage part is not separated from the current part. During the normal meter operation the potential links should be closed (position 1). Upon request, the potential links can be built under the meter cover.

Magnetic field detector (reed relay) triggers an magnetic field detected event and no more magnetic field detection event that are recorded in fraud detection log book if and when there was an external magnetic field (30-35AT) near the meter. This is used for security reasons as some public might try to influence the meters accuracy.

Every fraud attempt is recorded to antifraud detection log and alarm can be sent to operating centre if auto-dial is enabled. Alarm is also recognized by scheduled readings of meter state in AMR system.

The terminal cover can be long or short. The meter connection diagram is stuck on the internal side of the terminal cover.

3.3. Overall and fixing dimensions (MT381) Mounting and fixing meter dimensions comply with the DIN 43857 standard.

Fig. 7: Overall and fixing dimensions of an MT381 meter fitted with a long terminal cover



Fig. 8: Overall and fixing dimensions of an MT381 meter fitted with a short terminal cover

Fig. 8: Overall and fixing dimensions of an MT381 meter fitted with a switching device and a long

terminal cover

3.4. Metering system (MT381) Besides precision measurement of active energy and demand in a wide metering and temperature range, the metering system enables measurement of phase voltages and currents. Three (on request four) metering elements are built in the meter. The current sensor is the Rogowski coil (a current transformer with an air core), while a voltage sensor is a resistive voltage divider. Signals of currents and voltages are fed to the A/D converters, and then they are digitally multiplied so that instantaneous power is calculated. The instantaneous powers are integrated and summed in a microcontroller, as well as further processed.

Fig. 10: Block diagram of metering with Rogowsky coil

Fig. 11: Metering principle of Rogowsky coil

Fig. 12: Explosion view of the Rogowski coil

1. Rogowski coil frame 3. Two Rogowski coils (secondary winding)

2. Meter current loop (primary winding) 4. Printed circuit board

The metering elements ensure excellent metering properties:

1. Wide metering range 2. Negligible influence of disturbances and

influence quantities 3. Long-term stability so that meter re-

calibration is not required over its life 4. Long meter life time and high reliability in

use



Through current coil flows the current. Inside the air coils (Rogowsky coil) voltage is induced due to alternate magnetic field. Meter/measuring system measures induced voltage on measuring coils which is proportional to the current on input. On each phase there are two Rogowsky coils. The first coil measures energy and the second one is compensation coil that measures outside disturbance. Compensation value is substracted from measuring element.

Meter accuracy cannot be affected by external DC magnet. Magnetic system does not contain magnetic material that could be saturated by external magnet.

Meter accuracy cannot be affected by external AC field. Two Rogovsky coils are placed together as much as possible. In that case external AC field affects both coils in same amount and AC field is compensated.

3.5. Meter configuration (MT381)

Fig. 13: MT381 meter block diagram

4. Mx38y meter components 1. Power supply unit 2. Microcontroller with non-volatile FRAM

memory 3. RTC Internal real-time clock 4. LCD (Liquid Crystal Display) in compliance

with VDEW specification

5. LEDs 6. Two push-buttons (Reset, Scroll) and one

switch under the meter cover (Param) 7. Communication ports and channels :

P0 - IR optical port P1 - RJ11 read-only serial port P2 - M-Bus communication interface P3 - DLC modem

8. Inputs and outputs : Alarm inputs (option) Load control relays (option)

9. Switching device 10. Detectors of opening a meter cover and

terminal cover and magnetic field detector

4.1. Power supply unit The power supply unit is of a switcher type, which enables a meter to operate accurately in a wide voltage range. It enables a meter to operate accurately even when the meter is supplied from a single phase and voltage in the network is only 80% of the rated voltage.

4.2. Microcontroller with FRAM memory The micro-computer communicates with measurement ASICs, records active energy per phase for all phases in one or more tariffs and stores these values in various registers according to energy direction and active tariff. It basically consists off:

Micro-controller Non-volatile memory and Real-time clock

The microcontroller acquires signals from the metering element(s), processes them and calculates values of measured energy. The results are stored in energy registers for particular tariffs. It also calculates demands and register maximum demand in billing periods. The microcontroller also generates pulses for the LED and the output pulses, enables two-way communication via the optical port and the DLC modem, and drives the LCD display and the control outputs. It also enables registration of load-profiles and events into a log-book.

Non-volatile data memory permanently stores the important data such as energy registers, statuses, events, measuring data, to be safely stored in the case of grid voltage failure being longer than 200ms, profile data.

4.3. Real-time clock (RTC) A real-time clock integrated circuit with digital calibration holds an internal calendar that provides information about the year, month, day, day in a



week, hour, minute, second and leap year. The clock accuracy complies with the IEC 62052-21 standard for time switches.

A super capacitor (super-cap) is used as an auxiliary power supply which holds data for at least 150 hours. For complete charging of the super capacitor the meter should be connected to voltage for at least 35 minutes. The clock is driven by a crystal with 32.768 kHz frequency. Optional Lithium battery holds data up to two years. Supercap or Lithium battery are used to retain accurate clock during power loss.

Date and time are represented on the meter display like this:

Time: hh:mm:ss (hours:minutes:seconds) Date: yy.mm.dd (year.month.day)

Clock object consists of several time/date related attributes. These attributes are divided into:

Local time/date Time zone Daylight savings time (DST)

Time data format (attribute 2) is formed like this and its the same in all other objects used in the meter:

YYYY MM DD WD hh mm ss hh dddd CS

Year Month Day HourWeek day Minute Second Hundredhts Deviation Clock status

Fig.14: Time and date data format

Time zone is the deviation of local, normal time to GMT in minutes.

Clock status shows if DST is currently active or not 128 (DST is currently active current time/date

is in DST boundaries) 0 (DST is currently not active current

time/date is outside DST boundaries)

Daylight savings begin/end defines the local switch date and time when the local time has to be deviated from the normal time.

Daylight savings deviation contains the number of minutes by which the deviation in generalized time must be corrected at daylight savings begin. Deviation (in minutes shows the difference from GMT time and clock status active/inactive DST. Deviation range of up to 120 min.

Daylight savings enabled: to use DST, DST needs to be enabled with start and end date set also.

Clock time shift limit is maximum allowed time shift (in seconds) without registration of a time shift event. If

the time synchronisation is larger than the clock shift limit the meter will record the synchronisation as time setting.

4.4. Liquid Crystal Display LCD The 7-segment LCD display, with additional characters and symbols, complies with the VDEW specifications. Large characters and a wide angle view enable easy data reading.

Fig. 15: Liquid Crystal Display LCD (all segments)

Fig. 16: LCD display (real view)

Data are displayed in the right bottom corner by means of eight 8 mm high alphanumeric characters. The OBIS code (by IEC 62056-61) is employed for data identification (in accordance with DIN 43863-3). OBIS code is displayed in the left bottom corner by means of five 6 mm high alphanumeric characters. Additional symbols indicating energy flow direction are displayed in the left top corner. A physical unit of displayed quantity (data) is shown in the right top corner. The indicators of L1, L2 and L3 phase voltages presence are displayed in the middle of the top row. If certain phase voltage is not present, the indicator of that phase is not displayed (do not lights). The LCD display can be tested for malfunction and if all the segments are functioning. When the meter is in Auto scroll mode short press (2-3 sec) of the Scroll push-button switches meter to test mode, which lasts for 10 seconds and all segments are displayed. After expired test time the meter automatically returns back to Auto scroll mode.

4.4.1. Signal flags on LCD In the LCD bottom row there are eleven signal flags that indicate current valid tariff, meter status and alarms. The meaning of the flags depend on the type of meter. Shortcut meaning of each signal flag is engraved on the meter name plate below each of the signal flags, engraving can be custom defined and meaning is shown in the table below :



Flag Name Not displayed Displayed Blinking 1 T1/5 Active first tariff Active fifth tariff / param switch off 2 T2/6 Active second tariff Active sixth tariff / param switch off 3 T3/7 Active third tariff Active seventh tariff / param switch off 4 T4/8 Active fourth tariff Active eighth tariff / param switch off 5 MB No M-Bus device installed Atleast one M-Bus installed 6 SD Disconnector inactive Disconnector active 7 SQ GSM signal lower than -95dBm

GSM signal higher than -87dBm

GSM signal between 95dBm and 87dBm

8 REG/DLC Meter not logged in the GSM/DLC network

Meter logged in the GSM/DLC network with installation call made or not enabled (for GSM/GPRS)

GSM/GPRS modem registered but installation call wasnt made

9 DRO Meter data down-loading is in progress Data package is present in the AMR communication network

10 FF No fault Fatal fault SET Normal operation mode 11 EC Emergency Credit active Emergency Credit threshold limit expired

Table 1: Function of display flags If the FF code is displayed, the meter should be dismounted and sent to an authorized repair shop or to

the manufacturer for examination.

4.4.2. Tariff on display Active tariff can be shown on the display. Also a dedicated name can be constructed, but only with this numbers and characters: 1, 2, 3, 4, 5, 6, 7, 8, 9 A, B, C, E, F, H, I, J, L, P, S, U b, c, d, h, i, l, n, o, r, t, u

4.4.3. Console display format These objects are used to configure energy and demand display format. There is a maximum of 8 total digits to be displayed for energy or demand values. If needed, decimals can be set too. On display Active energy is represented in (kWh), reactive energy in (kvarh), and apparent energy in (kVAh) and demand in (kW). The length of the display is the first number of two digit number to be entered and second is number of decimals. Eight digits are possible to be displayed. If needed decimals can be set also, but are included in the 8 digit total. Display format examples:

60 6 digits, 0 decimals 82 8 digits, 2 decimals

4.4.4. Data display Data defined in Auto scroll sequence and in Manual scroll sequence are displayed on the LCD. Data from Auto scroll sequence are displayed in a circle - each is displayed for 10 sec. Scroll push-button should be pressed to start Manual scroll sequence. By pressing Scroll push-button display scrolls through data in a circle. Data remain displayed until the Scroll push-button is pressed again or until the time for automatic return to the Auto scroll sequence expires. Choice of displayed data depends on customers request at meter ordering. Most used data that can be displayed

are listed in the table bellow (complete list depends on meter FW). Because data register identifications have bigger identifications that display has available digits, these identifications are shortened and the table below shows these identification codes. Which of the registers will be displayed depends on the meter type.

4.4.5. Scalers To understand the energy value given by the meter, scaler units need to be considered. In some cases the scaler needs to be higher than 0 (factor 1) for energy values to fit in 8 digit display.

Scaler factor = 10x (x = scaler) Display Value = Register value * scaler factor * 10-3

Because display value is always shown in k units (103), the final value needs to be corrected with 10-3 Active Energy Value: 1234 Scaler (Wh): 1

Energy Value displayed: 1234*101*10-3 = 12.340 (kWh)

Code Data description 0.0.0 Meter serial number

C.1.0 Meter manufacturer number 0.9.1 Time

0.9.2 Date

1.8.0 Total imported active energy (A+) 1.8.1 Imported active energy in the 1st tariff (T1) 1.8.2 Imported active energy in the 2nd tariff (T2) 1.8.3 Imported active energy in the 3rd tariff (T3) 1.8.4 Imported active energy in the 4th tariff (T4) 15.8.0 Total absolute active energy |A| 15.8.1 Absolute active energy in the 1st tariff |T1|



Code Data description 15.8.2 Absolute active energy in the 2nd tariff |T2| 15.8.3 Absolute active energy in the 3rd tariff |T3| 15.8.4 Absolute active energy in the 4th tariff |T4| 2.8.0 Total exported active energy (A-) 2.8.1 Exported active energy in the 1st tariff (T1) 2.8.2 Exported active energy in the 2nd tariff (T2) 2.8.3 Exported active energy in the 3d tariff (T3) 2.8.4 Exported active energy in the 4th tariff (T4) 1.6.0 Total A+ imported maximum demand

2.6.0 Total A- exported maximum demand

F.F.0 Meter fatal error

Table 2: Data for LCD display

In certain cases error can appear on the display. The list of errors that can be seen on the display is:

Code Data description ERROR11 Ident format failed ERROR23 Ident not existing

Table 3: display error codes

4.4.6. Display of standard messages on meter LCD display and P1 It is possible for grid companies and suppliers to send standard messages concerning the supply of energy to the meter. These messages are displayed on the meter display and are also sent to port P1. Examples of messages to customer concern for instance:

Reason for (dis)connect, Reason for applying a threshold (limit) for

electric energy, Impending shortage of prepaid credit.

Messages concerning gas or other submetering devices, connected to M-Bus, can also be displayed on the electricity meter display.

4.5. LED The meter is provided with two red coloured LEDs on the front plate. They are intended for checking the meter accuracy. Impulse constant depends on the meter version.

Upper LED indicates active energy flow Lower LED indicates reactive / apparent energy

flow. One indicates active energy flow, the other reactive or apparent energy flow, all regardless direction (import or export). In normal meter operation mode, the LED emits pulses with frequency that is proportional to the measured power and is intended for meter calibration and testing. The LED is turned on and glows steadily if load is lower than the meter starting current. The impulse constant depends on the meter type and setting.

According to the meter measurement type LEDs can be enabled or disabled. If the value in the register is 0 the LED is disabled, and if the value is higher than 0 (there are only a few simple number that are usually used) the LED is enabled and blinking according to the constant number entered and energy consumption (impulses / unit).

4.6. Push-buttons and param-lock Two push-buttons are built in the meter cover :

Reset orange push-button is under the lid with a hinge and can be sealed independently from the meter cover,

Scroll blue push-button is always accessible. Its primary function is to scroll data from the Manual scroll sequence on the LCD.

Depending on the time of pressing the push-buttons and a combination of pressed push-buttons they enable:

Selection among the meter operation modes Testing the LCD Scroling of metering results and setting meter

parameters

Time of pressing the Reset push-button does not influence in its function.

For the Scroll push-button we distinguish 3 different pressing times :

short (t < 2 s) scrolling the display in Manual mode

long - (2 s < t < 5 s) selection of displayed submenu or function (disconnecting SD, credit, or ESC)

extended (t > 5 s) displayed data get one menu level back (e.g. if data from the third level are displayed, then the Scroll push-button should be pressed three times, and each time it should be kept depressed for more than 5 sec in order to return back to Auto scroll mode).

DURATION TP[S] COMMAND 0.2 < Tp < 2 SCROLL 2 < Tp < 5 ENTER 5 < Tp ESC

Table 4



Fig. 17a: Push-buttons

Fig. 17b: Push-buttons

Besides the above described push-buttons, the meter is provided with the third Param lock switch, which is built in the PCB under the meter cover. When unlocked, it enables to enter the meter programming in a laboratory. When locked, it is used as a hardware-lock against tamper attempt.

4.6.1. Reset push-button

Reset push-button can be locked by a seal.

THE PUSH-BUTTON PRESSING TIME TP [S]

COMMAND

2 < Tp < 5 MENU 5 > Tp RESET

Table 5: Reset push-button functions

Reset push-button functions are for switching the meter to test operation mode and for meter reset. This push-button is used when entering a test menu. The test menu can be entered only in the first five seconds after a meter startup if a meter parameter switch is open.

4.6.2. Scroll push-button

Scroll push-button functions are: - Invoking LCD display test - Scrolling data in Manual scroll - Switching to the meter test operation mode - Switching device disconnection or reconnection.

Fig. 18: Test of LCD display segments

DURATION OF PRESSING ON THE PUSH-BUTTON TP [S]

COMMAND

0.2 < Tp < 2 SCROLL 2 < Tp < 5 ENTER 5 < Tp ESC

Table 6: Scroll push-button functions

4.6.3. Auto scroll Auto scroll means normal common data display of internal objects listed in Auto scroll object. After power up, display is in Auto scroll mode and shows values listed in that object every 10 sec. consecutive in circle.

Meter can be reset also with meterview 5 application by issuing global meter rest script.

4.6.4. Global meter reset (only for testing purposes in laboratory)

The Reset and Scroll push-buttons are used to reset the meter by pressing appropriate push-buttons, following predefined time sequencies with Param lock switch in off position. The push-buttons pressings are tracked by messages on a display ( See Fig. 26: Normal meter reset). Manual reset procedure :

Power-up the meter Press Scroll push-button for 2-3 seconds,

the display shows test



BLUE Key

ORANGE Key

test

Display

Display

Display test

Meter power up

tbtb < 5s

tb > 5s Auto scroll

Display

Display test tbd > 3s

wait wait

Enter ESC Reset

Display test

Auto scroll

Display Display Display

Display

Display

Press BLUE or ORANGE key

Release BLUE or ORANGE key

Fig. 19: Meter reset procedure

Meter can be reset also with meterview 5 application by issuing global meter rest script.

4.6.5. Manual scroll Manual scroll means data display of internal objects listed in Manual scroll object. We can enter this mode by appropriate pressing the Scroll push-button. With pressing Scroll push-button data show on LCD display consecutive in circle, but stay shown until new push to Scroll push-button or until time for return to Auto scroll mode expires.

Press Scroll push-button and hold it while pressing and holding the Reset push-button untill display shows Esc

Release first Reset push-button, display shows reset and than Scroll push-button.

Meter can be reset with MeterView 5 application by issuing Global meter reset script.

4.6.6. Menu navigation After power up, meter is in auto scroll mode. Predefined menu is available by appropriate push-button pressing. (See Fig. 20)

A user interface has only two menus: Auto scroll and Manual scroll. The first one shows data stated in a list in the 'General display readout' object. Transition between a display of individual data from a list is performed automatically. By short pressing the Scroll push-button, the program goes to the Manual scroll menu where data are checked by successive pressing the Scroll push-button. A data list that can be checked in the Manual scroll is stored in the 'Alternate display readout' object. A switching device makes or breaks or emergency credit can be done with a Scroll push-button.

Three console period timings are (fixed and cannot be changed):

Exit period after last pressed push-button (default is 120s)

Autoscroll period (default is 10s) Backlight lit time after pressed push-button

(default is 60s)



Display Test

Auto Scroll

t = 6s

0-0:21.0.2

N0-0:21.0.1

Display registersDisplay Test

60s no activity

Connect

Enter

Credit

Credit

DisconnectCB Off

CB On Creditfirst time ?

EC SEL

Release Scroll key

Credit

Disconnect

Y

N

CB==Off

CB mode

Y

N

on

off

Y

START

Scroll key hold > 8s

LEGEND:

Scroll key release andpress again

SKH Scroll key hold

SKH

SKH

SKH

SKH

SKH

SKH

SKH

SKH

SKH

SCMDScroll command

SCMD

SCMD SCMD

SCMD

Figure 20: Menu navigation diagram

4.7. Communication ports and channels The MT381 meters are equipped with the following communication ports and channels:

a. P0 : Optical port IR communication interface b. P1 : RJ11 local interface c. P2 : M-Bus communication interface P3 : - DLC modem

Fig. 21: Communication structure of MT381



4.7.1. Optical port P0 - IR communication interface

Fig. 22: Meter readout via an IR optical interface

The optical port complies with the IEC 62056-21 standard mode C or DLMS-HDLC IEC 62056-46 and is used for local meter programming and data down-loading via PC, laptops or PDA devices. It is located in the right top corner of the meter. The communication through optical port is serial asynchronous with data transmission rate from 300 bit/sec to 115.200 bit/sec. Hand-held unit (HHU) or a device with equivalent functions can be connected to optical port. If the optical probe highest data transmission rate is lower than 19.200 bit/sec, then this data transmission rate should be the same preset, otherwise communication through optical port would not work.

Optical port setup in appropriate register consists of : communication type (IEC1107 or DLMS UA) communication speed (default and proposed) response time device address (manufacturing number) two passwords (for setting and

parametrisation).

Communication speed: Default baudrate is baud rate for opening sequence, proposed baud rate is baud rate to be proposed by the meter, relevant for IEC1107. Communication speed up to 115200 bit/sec is possible, recommended baud rate is 38400 bit/sec.

Response time: Communication response time is time between the reception of a request and the transmitting of the response and can be 0 to 20ms or 0 to 200ms.

Device address is intended to identify a meter in the group of meters. Each meter in one group must therefore have a unique number.

4.7.2. Port P1 - RJ11 Interface Port P1 is serial read-only interface for gas, gas valve, thermal and water meters. There is no separate interface for electricity meters since they are a part of metering system. P1 port enables communication between several types of Service

Modules and a Metering System. The measuring device has only one port P1, which is connected with splitter. It is possible to connect more than one device with OSM (Other Service Module).

The meter sends P1 data to the port every 10 seconds in order to receive frequent and up to date results. Readout of data (up to 32 different data) can be set in Data read-out register and can consist of electricity meter data and submeter for gas, water and heat data.

More than one system may be connected to the measuring device, each system may request data input and all systems will receive the same data sent by the measuring device. More than one OSM (Other Service Module) can be connected to P1 through RJ11 connector and Splitter, activated or not. All signals are compliant with TTL levels (max current is 10mA and voltage 30V). The port is activated by raising the request signal to 5V. The connector is RJ11. The metering system holds a female connector, standard RJ11 plug can be plugged in. The connector in the metering system is physically accessible at all times and should not be sealed or protected by a sealed cover. RJ11 pin asignment :

Pin # Signal name Description 1 2 Request Input 3 GND Ground 4 5 Data Output 6 Table 7: Signals on RJ11 connector

Figure 23: P1 port connection

Fig. 24: Diagram for connecting more than one OSM device to Port P1



P1 port settings: Communication type is set to IEC 62056-21

(IEC1107) Initial and proposed communication speed is

set to 9600 bit/sec Response time is set to 200ms No addressing is necessary No passwords is used

P1 port readout: With this object data readout information can be set. This information can be also retrieved remotely, usually over optical interface or over modem communication.

Consumer messages: If a device is connected, the meter will send the message (code and/or text) over the P1 interface every 10 seconds. The meter has storage capacity for one numeric message code and one 1024 character text message. Message codes and text messages are handled independently, but in the same way.The messages are sent over P1 port every 10 seconds.

Consumer message text can be shown on P1 port and on the display. Value is text message code with numeric 64 digits.

Consumer message code is sent to P1 port without any further interpretation, with maximum of 1024 characters.

4.7.3. M-Bus communication interface (P2) Port P2 is M-Bus communication interface for gas, gas valve, thermal (heat/cold) and water meters, integrated in MT381 meter according to EN 13757-2 and EN 13757-3 (EN 13757-4 T1/T2 mode for wireless M-Bus communication). M-Bus micro-master specifications. It enables the communication between several types of meter and an electricity meter, to which they are connected.

Fig. 25: M-Bus: wired and wireless infrastructure (master (MT381) slave configuration)

P2 port enables connection of up to 4 slave devices (water, gas and heat meters), where maximal length of wiring is 50 m. In the wired version the electricity meter functions as the communication master, the other devices connected to the M-Bus function as communication slaves. M-Bus is a protocol that is described for remote reading of meters in the European standard EN 13757. It is a two wire system that provides power to the devices. The requirements for M-Bus are given in standard EN 13757 2. The bus interfaces of the slaves are polarity independent the two bus lines can be interchanged without affecting the operation of the M-Bus devices. No physical access for P2 port is possible by customer. The connections to the P2 port are located behind a sealable lid. Due to uniformity reasons and independency of used communication medium all data exchange over the wireless and wired connection must be/are encrypted. The electricity meter, functioning as Bus-Master in the wired architecture and as Listener in the wireless infrastructure, will gather and store information from all connected meters or devices and forward this information to the Central Access Server (CAS). It will also control (e.g.) the gas valve. The maximum number of M-Bus devices associated with a single E-meter is four. This includes all wired and wireless M-Bus devices. Wireless meter data are exchanged according to EN 13757 4 standard. Devices are connected through the wireless (RF) M-Bus connection according to the T1/T2 mode of this standard. The electricity meter is the master device, meaning that all communication is initiated from it. If there is an alarm in a connected device then this will be indicated during the next reading of the device. It will not generate an immediate alarm. The maximum number of slaves in a master/slave wired configuration, shown in figure below is four.

Fig.26: M_Bus master slave configuration and dongle interface



As alternative solution for data exchange there is a combination of hardware or software paired meter-dongle. The dongle-master interface must be confirming to the wired M-Bus specifications. The wireless communication between the dongle and the meter may be vendor specific, non-standard, with the following restrictions: supplier should clearly show that the wireless communication is encrypted with same security level as for wireless communication is required; dongle and meter may be a hard coded pair, individual dongles and meters need not be interchangeable. The dongle connected M-Bus devices are regarded as wired M-Bus devices.

Communication specification: The communication speed is 2400 baud. The electricity act as an M-Bus master and

the external device as an M-Bus slave. A maximum of 4 external slave devices is possible.

The standard used for the application layer: EN 13757-3

The standard used for the physical and link layer: EN 13757-2

The On Request Read of G-meter is a service for electricity meter read invoked by a call centre agent during a customer call. The meter read represent the current reading of the display of the meter. Generally MBUS is composed by M-Bus protocol EN 13757-3 and physical carrier (electrical specification).

During standard operation the electricity meter will collect the consumption data by sequent polling the M-Bus by the available device addresses. A maximum 4 of the external M-Bus meters could be read. The retrieved data are organized in four measuring channels. One channel per each connected meter.

Fig.27: M-Bus channel model

Up to 4 values related to consumption data can be extracted from the M-Bus data frame and stored to electricity meter registers. Rule how to map data from the M-Bus data frame to electricity meter register could be defined by setting 4 VIF register for particular channel.

Read consumption values are represented forward to the system as COSEM extended register. Billing reads, data, could be retrieved daily, weekly, monthly at specified time or on request from the system.

Data exchange over the M-Bus wireless and wired connection can be encrypted. MT381 meter as the master device initiate communication on M-Bus interface. Because of battery powered operation of

submeters, reading periods should be rare, so they are default set to 1 hour. Auto-install procedure is implemented. It is invoked by MT381 meter power up, by pressing the Reset push-button or by command over port P0.

4.7.3.1. M-Bus related objects

Main M-Bus related objects for each connected device or channel are:

For identification there are Identification numbers or device IDs:

o Device ID1: M-Bus equipment identifier (4 instances, 1 per channel)

o Device ID2: M-Bus configurator data identifier (4 instances, 1 per channel)

M-Bus master value holds last read value

Identifiers

1 2 4 5 6 7 8

Cold Water

1 2 4 5 6 7 8

Hot Water

1 2 4 5 6 7 8

Water

1 2 4 5 6 7 8

Gas

M-Bus

Electricity Meter Mx38x

Channel 4 Register 1

.

.

.

Register n


.

.

.

Register n


.

.

.

Register n


.

.

.

Register n

Channel x

Setup Profile

Disconnect Control Control Log

Values Value 1

Value 2 Value 3

Value 4



Status of profile M-Bus Event code M-Bus event log Device type defines submeter medium (gas,

water, heat,). We can read current captured results. Hourly readings of measured values from

installed M-Bus submeters are captured to M-Bus master load profiles (hourly captured results).

Events and alarms captured from subdevices are recorded to M-Bus master event logs.

With M-Bus master disconnect control it is possible to switch the valve (intern or extern) of the M-Bus submeter. For gas meter it is control of opening and closing of the gas valve.

M-Bus disconnect control scheduler to dedicate the time point for connection or disconnection.

M-bus disconnector script table for remote reconnect and remote disconnect services of the M-Bus disconnector object.

Time of the event (e.g. valve opening or closing) and control event codes are recorded to M-Bus master control logs.

Control log: Mx38y meter records time and code of the switching event (e.g. valve opening or closing) in the control log.

M-bus configuration flags (additional M-bus configurations)

M-Bus client (subdevice) settings consist of Primary Address (PA) and capture DIF-s and VIF-s. They define which values and in which units should be captured from subdevices.

M-bus alarms: four different groups of alarms are used for M-bus events, directly related to the devices, connected to e-meter:

o M-bus communication error o M-bus fraud attempt o M-bus device installed o M-bus client decryption failed.

After installation of M-Bus device, there is a value in the primary address PA. The meter recognizes it and starts to communicate with the M-Bus device. Attention! Initial setting of subdevices PA should be 0 (zero), to allow Mx38y meter to set next free value during installation. If it is not zero, then all PA-s of submeters must be different to prevent collision during installation process.

4.7.4. Communication profiles (P3) The communication profiles for MT381 meters is PLC . DLMS/COSEM uses only the pull mechanism for the application layer.

4.7.4.1. PLC communication interface (MT381) PLC is power-line communication (DLC = Distribution Line Carrier) over the low-voltage grid. PLC is about power-line communication over the low-voltage grid, which has interested several equipment and utilities during the last decade, trying to achieve more reliable communication over the power lines. The main advantage with power-line communication is the use of an existing infrastructure. Wires exist to every household connected to the power-line network. The power-line network is a large infrastructure covering most parts of the inhabited areas. In power distribution the power is typically generated by, e.g., a power plant and then transported on high-voltage (e.g., 400kV) cables to a medium-voltage substation, which transforms the voltage into, e.g., 10kV and distributes the power to a large number of low-voltage grids. Each low-voltage grid has one substation, which transforms the voltage into 400 V and delivers it to the connected households, via low-voltage lines. Typically several low-voltage lines are connected to the substation. Each low-voltage line consists of four wires, three phases and neutral. Coupled to the lines are cable-boxes, which are used to attach households to the grid.

A DLC modem for remote two-way communication is built into the meter. The DLC modem is connected to the low voltage network internally via L3 phase (MT381). For successful communication with the meter it is therefore necessary that L3 phase and neutral conductors are connected to the meter. If the MT381 meter is installed in a single-phase network, the phase conductor should be connected to its L3 phase terminal.

PLC consists of three major parts: The DLC meter The Concentrator and Communication Node

(CCN) The Operation and Management System

(OMS)



Customer

Communication path

0.4kV 10kV

Meter DLC

CCN

Central computer

DLC

OMS

Fig. 33: Typical PLC system

The DLC modem enables two-way communication with a data concentrator built at the low voltage side of a substation via low voltage network and uses SFSK (Spread Frequency Shift Keying) modulation. DLC communication system is based on Intelligent Network Management principle (find, install, deinstall, dynamic addressing). Data transmission rate via low voltage network can be up to 2,400 bit/sec. Data transmission rate between the microcontroller and the DLC modem is serial asynchronous with data transmission rate 4,800 bit/sec.

Coupl

er

M odu la to r

D em odu la to r

Pow

er

grid

L T C

D B

M A C

IS A

C on tro lle r

D U ID

Fig. 34: Meters DLC system

Coupler is LC filter with transformer preventing against high grid voltages. Modulator demodulator are the couple, modulating demodulating signals under choosing demodulating technique (SFSK spread frequency shift keying) which means mark frequency (fm) for digital value 1 and space frequency (fs) for digital value 0. SFSK == |fm fs| > 10 kHz. Carrier frequency is always in pair means fm & fs. For the indoor system are defined as shows Napaka! Vira sklicevanja ni bilo mogoe najti. are described as central frequencies. Meter system use band A. Systems with deferent frequency pair can not hear each other.

Fig. 35: Frequency bands according to CENELEC

AMR readout: To establish the system for automatic meter readout (AMR) two basic components are required:

A meter: MT381 (Server) A concentrator P2LPC (Client)

Communication between the meter and the concentrator is performed via a DLC modem that is built in the meter and the concentrator. For correct recognition of the meter by the concentrator, some identification numbers that are stated below should be written.

Device number Device factory number

PLC Network Management process includes management services for discovery and registration of network elements, service for detecting if network element responds (ping), service for clearing alarms (clear alarm) and service for repeater status update (repeater call).

10 20 30 40 50 60 70 80 f[kHz] 90 100 110 120 130 140 150

3 9 95 125 140 148,5

A B C D



4.8. Inputs and outputs (option) Every meter can have functions that use input and output terminals. These objects are used to configure and show meters input and output controls. There are some limitations in use since different functions are shared on input and output terminals and some functions (for hardware reasons) are not available on all meters. Correct configuration of this object results is the key in functionality of input/output functions. These functions can be used to operate with:

Relay output MOS-FET output Outputs for active switching device (SD) Alarm input External key input / No voltage external key

input

4.8.1. Terminal functions Terminal connectors serve as input or output for certain meter function. Each function has its own designated number by which it can be recognized in the configuration:

Active switching Device output Alarm input / Passive External Key

External Scroll / Reset Key

4.8.2. I/O control

Numbers represent meter terminal numbers on which folowing functions could be executed.

71 - Defines active switching device output 72 - Defines active switching device output 15 - Defines Alarm Input 2 or External Key / 51

- Defines Passive External Key 85 - Defines Alarm Input 1 or External Key

4.8.3. Alarm inputs

An input for detecting auxillary alarm is available. It is open collector optomos type and can be low voltage, high voltage or special external key input. Input-output connection terminals are placed on the right side of the meter terminal block and on the upper additional plate. Input is controlled by voltage on terminals. Control voltage is from 3V to 24V or 230 V AC/DC .. Potential free external key input is simple passive input capable to detect a presence of short circuit on dedicated terminals (50 and 51).

Fig. 36: Position of alarm input

4.8.4. Load control and Service control output Load control output is a bistabile relay. The relay is capable of switching 250 V, 6 A load. Service control output is optomos relay capable of switching 250 V, 100 mA load. Switching of either of the outputs can be controlled via built in time of use (TOU) by setting the switching times for corresponding tariffs. By default outputs are active when the low tariff is active. Disconnect control state defines initial output state and disconnect control mode defines the mode of operation for each of outputs. Auxiliary terminals for connection of outputs are on the left side of terminal block (See fig 41).

34 Relay output 35 Common

Fig. 37: Position of outputs

Disconnect Control Mode defines the mode of operation of Disconnect control. These are possible modes:

Mode Description

0 None. The disconnect control object is always in connected state Disconnection: Remote (b) 2 Reconnection: Remote (a) Disconnection: Remote (b) 4 Reconnection: Remote (a)

Table 8: Disconnect modes

80 15/51 72 71



Disconnect Output State shows the actual physical state of the disconnect unit.

(1) True (0) False

Disconnect Control State defines the internal state of the disconnect unit. In the state Disconnected (0) the relay is open. In the state Connected (1) the relay is closed. State Ready to reconnection (2) is not used. Possible control states are:

(0) Disconnected relay open (1) Connected relay closed

4.8.5. MOS_FET output service Service Control registers are used to configure OPTO-MOS output with maximum capability of 0,1A at 250V. Service control terminals are:

33 MOS-FET output 35 Common

Fig.38: Service control terminals

This output can also be triggered via tariff program.

With Service Control Mode different types of switching can be set. Available mode options are the same as with load control.

Service Control State shows state of the MOS-FET. In the state OFF (0) the load on the MOS-FET is disconnected. In the state ON (1) the load on the MOS-FET is connected.

With Service control power on delay, relay switch delay at power up can be set and is used when OPTOMOS state should be switched on. Desired delay time should be set in seconds (s).

With Service control switch on delay, relay switch delay at state switch can be set and is used when OPTOMOS state should be switched on. Desired delay time should be set in seconds (s).

Disconnect service control controls the connection and disconnection of the relay. Switching of either of the outputs can be controlled via build in time of use by setting the switching times for corresponding

tariffs. See also TOU settings. By default outputs are active when the low tariff is active.

Disconect control mode defines the mode of operation of Disconnect control

Mode Description

0 None. The disconnect control object is always in connected state Disconnection: Remote (b) 2 Reconnection: Remote (a) Disconnection: Remote (b) 4 Reconnection: Remote (a)

Table 9: Disconnect modes

Disconnect Output State shows the actual physical state of the MOS-FET unit.

(1) True (0) False

Disconnect Control State defines the internal state of the disconnect unit. In the state Disconnected (0) the MOS-FET is open. In the state Connected (1) the MOS-FET is closed. State Ready to reconnection (2) is not used. Possible control states are:

(0) Disconnected MOS-FET open (1) Connected MOS-FET closed

4.8.6. Input/output status This is read only information of I/O status. I/O Status is represented as a decimal number which is a result of all input or output function statuses. Each input or output function has its own designated bit in 16 bit input or output register. This bit can be enabled (logical 1) or disabled (logical 0). According to that, HEX number is a result of the whole binary register word. Not all bits in the register are used and some are reserved for future functions.

4.9. Switching device Switching device (SD) is used for remote disconnection and reconnection of electric network to individual customers. The meter controls the SD directly. Control can be performed locally (from the meter) or from a remote control centre using the meter AMR communication. MT381 meter has plug-in external switching device which is equipped with terminal cover which can be sealed. Assembly is simple since one part is inserted into the meter terminal block, and another part is extension of the terminal block.



Fig. 39: ZO350-D2 plug-in switching device 1

Fig. 40: ZO350-D2 plug-in switching device 2

Fig. 41: Assembly of ZO3 plug-in switching device

Figure 42: MT381 meter with attached SD

5. Meter functions

1. Internal RTC clock 2. Activity calendar (TOU time-of-use energy

registration tariff program) 3. Measurement of electrical energy 4. Maximal electrical power (demand) 5. Instantaneous values (U, I, P) 6. Load profile recorder

Meter profile status 7. Billing profile recorder 8. Energy and power limitation, demand and

current supervision Disconnect control

9. Errors and event logs Events Alarms Power failure log

10. Power quality supervision 11. Identification 12. Security 13. Prepayment functionality



Fig. 43: Date and time data format

5.1. Activity calendar and TOU registration

The real-time clock enables complex daily and weekly tariff structures and a few of seasons in a year for which certain tariffs should be active. Different actions can be performed with tariff

switching like registering energy values or switching on/off bi-stable relay. Different combinations of the tariff program are avaliable:

Up to 8 tariff rates Up to 12 seasons Up to 12 day types

YYYY MM DD WD hh mm ss hh dddd CS

Year Month Day HourWeek day Minute Second Hundredhts Deviation Clock status



season_profile ARRAY[4]

Season STRUCTUREseason_profile_name

OCTETSTRING[1]season_start

OCTETSTRING[12]week_name

OCTETSTRING[1]

week_profile_tableARRAY[4]

week_profile STRUCTURE

week_profile_name OCTETSTRING[1]

Monday day_ID UNSIGNED

Tuesday day_ID UNSIGNED

Wednesday day_ID UNSIGNED

Friday day_ID UNSIGNED

Thursday day_ID UNSIGNED

Saturday day_ID UNSIGNED

Sunday day_ID UNSIGNED

calendar nameOCTETSTRING[1]

day_profile_tableARRAY[4]

day_profile STRUCTURE

day_scheduleARRAY[8]

day_IDUNSIGNED

day_profile_action STRUCTURE

start_timeOCTETSTRING[4]

script_logical_nameOCTETSTRING[6]

script_selectorLONG-UNSIGNED

Activity Calendar (Class_id:20)

1.logical_name

2.calendar_name_active

6. calendar_name_passive

5.day_profile_table_active

4.week_profile_table_active

3.season_profile_active

7.season_profile_passive

8.week_profile_table_passive

1.activate_passive_calendar

9.day_profile_table_passive

10.activate_passive_calendar_time

Fig.44: Activity calendar structure

To handle different tariff structures an instance of the COSEM class Activity calendar is used. It is used to store energy and demand according to tariff rate schedule. It is a definition of scheduled actions inside the meter, which follow the classical way of calendar based schedules by defining seasons, weeks and days.

After a power failure, only the last action missed from Activity calendar is executed (delayed). This is to ensure proper tariffing after power up.

Activity calendar consists of two calendars, active and passive, and an attribute for activation of passive calendar. Changes can be made only to passive calendar and then activated to become active calendar. Each calendar has following attributes:

Calendar name Season profile Week profile table Day profile table

Calendar Name typically contains an identifier, which is descriptive to the set of scripts, which are activated by the object. The season profile table can be divided into 12 periods (seasons), during which different week tables are applicable. FF value is used for not specified fields. Season profile consists of:

Season name Season start date & time Week name



The week profile table determines the day profile table applicable for particular week day. 12 week tables are available one week profile per season. Since week day tables are only divided into days, Monday to Sunday without time data, they are repeated every week while they are valid according to season profile. Value 255 is used for not specified field. Week profile consists of:

Week name Weekdays

The 12 day profile tables (to cover weekdays, Saturdays, Sundays and special days) are divided into day actions, which define individual tariff periods for energy and power. Each of these day actions is defined by the entry of start time. Up to 16 daily actions (switching points) can be defined per one day

table. FF and 255 values are used for not specified fields. Day profile consists of:

Weekday name Day start time Script table (usually tariff script table) Script names (S1-S16)

Change Over to New Switching Program: new tariff program structure is entered to passive calendar and change over time and date are entered to attribute active_passive_calendar_time of the class Activity calendar. On entered time and date content of active calendar will be replaced by tariff structure stored in passive calendar. Immediate activation can be done by setting the activation date to the current date or with invoking the method active_passive_calendar. For not specified use FF (e.g. FFFFFFFFFFFFFFFFFF800000)



Passive Tariff Program

Active Tariff Program

season_profile

season

week_profile_table

calendar name

day_profile_table

day_profileday_profile

week_profileweek_profile

season

season_profile

season

week_profile_table

calendar name

day_profile_table

day_profileday_profile

week_profileweek_profile

season

Copy Passive to

ActiveTariff

Program

Execute method

ActivatePassive Calendar

Time

Fig.45: Passive to active calendar switch

Special days: exception days like holidays can be preset in an object, which is instance of COSEM class Special days table. There is space for 64 special days entries.

With Register activation registers which values should be recorded and stored are determined. Selection of registers depends on meter type and configuration. Attribute 2 of this object shows which registers are available in the meter to register. There is a separate energy and maximum demand object where data to register can be set. Energy or demand

objects can therefore be set separetly with diferent masks.

Register assignment Energy register assignement includes all 88 rated energy objects from the meter.

Maximum demand register assignement includes all 56 rated maximum demand objects from the meter.

Tariff script table is intended for certain actions to be performed according to tariff program (activity calendar).



Tariff switch source determines the tariff triggering. Only Tariff switching with internal tariff program (1) is possible.

With tariff synchronization different tariff switching modes can be selected. There are two options:

Tariff not synchronized with measuring period (0)

Tariff synchronized with measuring period (1) With option 1 the tariff switches at the time that is selected in the calendar program and with option 0 tariff switches according to the calendar and waits with the switch till the measuring period is over.

Currently active tariff is used to get information about which tariff is currently active. Information in the register is represented with a number that represents certain tariff.

5.2. Internal clock

In the object Clock we set local time, time zone (attention: East of GMT time



measuring period that can be later used for the formation of billing values.

Fig.47: Measuring principle

Q+ S+

P+

- Cumulative Max Demand Plus (All,T1-T8)- Maximum Demand Plus (All,T1-T8)- Energy Plus (All,T1-T8)- Cumulative Max Demand Minus (All,T1-T8)- Maximum Demand Minus (All,T1-T8)- Energy Minus (All,T1-T8)-----------------------------------------------------------

- Active Max. Demand Absolute (All,T1-T8)- Energy Absolute (All,T1-T8)-----------------------------------------------------------

- Current, Voltage L1 - L3

P ( 1-0:1.2.0 - 1-0: 2.8.8 )Q ( 1-0:3.2.0 - 1-0: 4.8.8 )S ( 1-0:9.2.0 - 1-0:10.8.8 )

Pd abs ( 1-0:15.4.0 - 1-0: 15.6.8 )E ( 1-0:15.8.0 - 1-0: 15.8.8 )

u/i ( 1-0:31.7.0 - 1-0: 72.7.0 )Q- S-

P-

Fig.48: Measured energy and demand

5.3.1. Energy Measuring principle is shown on figure below. Achieving measurement signals is made from Rogowsky sensor. Analog signals are fetched from analog sensor and are transformed into the digital form where calculate procedure is performed. The results are stored in the internal registers, where they wait to be fetched by the meters micro-controller.

Uref T

Referencevolatage

Time base

Volatege path

Current path

Sample

Sample

Sample

Sample Correction

Correction

EEPROMCorrection

i

u( )uU

( )iI

u(t)

i(t)

Udc

fr

( )uU

( )iI

nu

ni

nu

ni

uu ,

ii ,

uu , ii ,

P,Q,S,PF

U,I,f,

f ~ Pn

N

n

i IUNP .1

1

=

=

Digital sectionAnalog section

Fig.49: Measuring principle

Active energy The micro-computer records the active energy for all phases in one or more tariffs (rates) and stores these values in various registers according to energy direction and active tariff (rates).

Active energy import (+A) Active energy export (-A) Active energy absolute (I+AI+I-AI) Active energy (I+AI-I-AI)

Reactive energy Reactive energy import (+R) Reactive energy export (-R) Reactive energy Q1 (+Ri) Reactive energy Q2 (+Rc) Reactive energy Q3 (-Ri) Reactive energy Q4 (-Rc)

Apparent energy Apparent energy import (+VA) Apparent energy export (-VA)

5.3.2. Demand The meter calculates an average Pd demand in a time interval as a quotient of registered energy during measurement period and Tp elapsed time.

After completion of the measuring period this value is stored to the register for previous measuring period and compared with highest maximum value stored in the relevant register and, if larger, stored as new maximum value at its position. At the same time, a time stamp is stored representing the time conclusion of measuring period. The maximum values formed in the individual tariffs are added at the end of the reset period to the memory storage as historical values and current cumulated maximum is reset to zero value. Up to 18 historical values can be stored. The oldest preliminary value is deleted each time a new value is stored.

At the end of billing period demand registers (1.4.0, 1.5.0, 1.6.0) are recorded and stored prior being set back to zero when new period starts.

A billing reset is always synchronized with measurement period 1. Tariff changeover synchronization with measurement period could be



parameterized. This means that event does not occur at the end of the measuring period but during the measuring period, which has influence on demand measurement in current tariff.

Active (P)Reactive(Q)Apparent(S)

TimeTd

E(n)E(n-1)

EnergyDemand = (E(n) - E(n-1)) / Td

Fig. 50: Demand

Active demand Active energy import (+A)

Current demand Last average demand Maximum demand Maximum demand rate

Active energy export (-A) Current demand Last average demand Maximum demand Maximum demand rate

Active power Active power (abs(Q1+Q4)+abs(Q2+Q3)

Current interval demand Last interval demand Maximum demand Maximum demand rate

Reactive demand Reactive energy import (+R)


Reactive energy export (-R) Current demand Last average demand Maximum demand Maximum demand rate

Apparent demand Apparent energy import (+VA)


Apparent energy export (-VA) Current demand Last average demand Maximum demand Maximum demand rate

Instantaneous values Instantaneous voltage Instantaneous current Power factor (+A/+VA):

Minimum power factor Last average power factor Instantaneous power factor L1, L2, L3 instantaneous power factor

Instantaneous active import power (+A) Instantaneous active export power (-A) Instantaneous reactive import power (+R) Instantaneous reactive export power (-R) Instantaneous apparent import power (+VA) Instantaneous apparent export power (-VA) Instantaneous power factor Instantaneous net frequency Instantaneous active power (+P) Average voltage Demand according to averaging scheme 3 Active import demand according to average scheme 3

Average import power Last average



Active absolute demand according to averaging scheme 3

Average total Last average

Apparent power + according to averaging scheme 3

Current average Last average

Averaging scheme 3 (Pavg3 for active and Savg for apparent demand) is realized with sliding window of known size. The size is determined with two parameters. First is the number of periods considered while the second is the duration of the period. Interface consists of two distinctive registers. First represents current average while the second resembles last average.

Last average provides the value of the energy accumulated (over the last number_of_periods*period) divided by number_of_periods*period. The energy of the current (not terminated) period is not considered by the calculation. Where last number of periods equals N and period equals T. The size of the sliding window (area of intrest) is thus T*N.

Fig.51: Calculation of demand over a known period with sliding window

Current average provides the current value (running demand) of the energy accumulated over area of intrest Curr.

Fig.52: Calculation of demand over a known period with sliding window

5.3.3. Maximum (power) demand measurement The real-time clock generates a demand period. Demand is calculated as an average value over the demand period. The following demand periods can be set in the meter: 5, 15, 30 or 60 minutes. At the end of the demand period, calculated demand value is stored, then compared with the maximum demand and if larger, new value is stored to the maximum demand register. In this way, the maximum demand value is calculated until it is registered at the meter billing time and then reset to zero. Attention! Maximum demand period can be set only at production time, it cannot be changed later.

5.4. Billing profile recorder Measuring values are the basis for preparing an invoice paper. Billing recorder implements periodical storage of energy and maximum demand registers to nonvolatile storage. Registers could be captured periodically or aperiodically. They are stored at the end of a billing interval (at billing time) to billing record. There are two recorders each with up to 15 objects and time stamp, with up to 4 different billing times (they can be single or periodical) and 2 different modes (only capture or with maximal demand reset at billing time). The meter keeps billing results for up to last 18 billing periods (months). Billing times and number of billing periods are set in the factory and cannot be changed. Billing reset can be performed remotely via communication channel. Billing results cannot be displayed, they can be read out via communication channels.



Captured objects 2 3 4 6 8

Number of records BP1 60 49 42 32 26 Number of

records BP2 38 31 26 20 16

Table 9: Approximate net capacity of the billing profile recorders BP1 and BP2 (clock register is already included):

5.4.1. Billing Billing implements storage of energy and maximum demand registers to nonvolatile storage. Registers could be captured periodically or aperiodically according to settings in the Single Action Schedule implemented in SingleAction module. In addition registers can be captured aperiodically with command over communication port.

Script 1:

IC Class:

Script table

Logical name:

0-0:10.0.1.255

Method 1:

execute

Action 1:

execute 1-0:98.1.0 capture

End of Billing Script Table

Script 2:

Action 1:

execute 1-0:98.2.0 capture

IC Class:

Single Action Schedule

Logical name:

0-0:15.0.0.255

Executed script:

0-0:10.0.1.255 (1)

Type:

5

Execution times:

Time_date 1

Time_date 2

Time_date 3

Time_date 4

IC Class:

Profile generic

Logical name:

1-0:98.1.0.255

Capture period:

0

Capture objects:

clock,

object1,

object2

objectn

Buffer:

clocki, object1, object2, , objectn

clocki+1, object1, object2, , objectn


clocki+m, object1, object2, , objectn


Entries in use:

m

Profile entries:

m

Method 2:

Capture

Method 1:

Reset

Billing data scheme 1

IC Class:

Profile generic

Logical name:

1-0:98.2.0.255

Capture period:

0

Capture objects:

clock,

object1,

object2

objectn

Buffer:

clocki, object1, object2, , objectn



clocki+m, object1, object2, , objectn

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