automation in scada, substation & metering

Automation in SCADA, Substation & Metering

18-Feb-12 1

ARUNACHALAM ADDITIONAL DIRECTOR

National Workshop on

Emerging Technologies in Electrical Power Engineering

17-18 February 2012

Silicon Institute of Technologies Bhubaneswar, Orissa

CPRI, BANGALORE

18-Feb-12 CPRI, BANGALORE 2

Outline

• Power System Automation – SCADA

– DA

• SUBSTATION AUTOMATION

• Metering System

• Smart Grid

Central Power Research Institute

MINISTRY OF POWER

GOVERNMENT OF INDIA

ESTABLISHED IN 1960

AUTONOMOUS SOCIETY IN 1978

RESEARCH

TESTING

CONSULTANCY


1) Central Power Research Institute, Bangalore. 2) Switchgear Testing & Development Station, Bhopal. 3) Ultra High Voltage Research Laboratory, Hyderabad. 4) Regional Testing laboratory, Noida. 5) Thermal Research Centre, Nagpur. 6) Regional testing Laboratory, Kolkata 7) Regional testing Laboratory, Guwahati

Central Power Research Institute - Units


Testing of power apparatus for 1. Electrical test 2. Insulation test 3. Thermal test 4. Stress test 5. Environmental test 6. Mechanical test 7. Seismic qualification test 8. Short time current test up to 300 kA rms 9. Direct testing upto 2500 MVA capacity 10.Synthetic testing 11.HV test upto 800 kV 12.Impulse test 13.Ingress protection test 14.Dielectric property test 15.EMI-EMC test 16.Heat run test 17.Flame proof test 18.Test for energy efficiency and many

more.

ISO 17025 ISO 9000

CCAR - CENTER FOR

COLLABORATIVE RESRACH

CPRI FACILITIES

PROTOCOL LABORATORY a) IEC 62056 b) IEC - 60870- 5- 101 c) IEC - 60870- 5- 103 d) IEC - 60870- 5- 104 . e) IEC - IEC 60870-6 . f) DNP 3.0 g) IEC 61850

18-Feb-12 CPRI, BANGALORE

5

OVERVIEW ON POWER SYSTEM AUTOMATION…

Acquisition of Information


POWER SYSTEM AUTOMATION

Availability of Information

Decision making

Analysis of the Information

From end points – meters, DTR, Feeders, RMUs

Communication and networking, DAS, AMR

Applications – EMS, DMS

O&M, Control, Planning, MIS, ERP, MBC

MCC Master Control Center

Communication Connectivity

SUBSTATION SUBSTATION

Generic - Automation Architecture


IT systems

VSAT, MPLS, FOC, GPRS

System strengthening

• Feeder re-configuration

• Conductor size

• LT: HT ratio

• DTR

• Load balancing

• Improving tail end voltage

Automation

• RMUs.

• Sectonalisers

• Auto re-closers

• Fault Pass Indicators (FPI)

• Communication systems.

• DMS functions.

Typical Automation Functions

System Centric Function Customer Centric

Function

MIS Related Function

Substation monitoring &

control (Local & Remote)

Reduced outage Technical loss reduction

DTR monitoring Reduced interruption Commercial loss reduction

Remote control of RMU &

sectionalizes

Better voltage System information for

planning

Planned system operation Planned load shedding Load forecast

Power transformer

monitoring

Improved reliability Optimal network planning

Load monitoring & control Quick service restoration Energy audit

Condition monitoring &

maintenance

Billing & Payment GIS mapping

TCMS / IVRS Asset management


AMBIENCE

• Indian electricity act

• Open access

• De-regulation

• Reforms

• Energy conservation act

TECHNOLOGY

• Computing platforms

• Measuring technology

• Interfacing

• Networking

• It enabling

• Communication

THE STANDARDS

• Open systems

• Communication protocols

• Information access

THE NEED

• Data / information

– Customer

– Management

– Operation

• Historical

• Efficiency improvement

Automation - Drivers


10

Network application overview

The SCADA

systems

caters to the

whole of

Karnataka

state which

has five

Distribution

companies

and 23

major

generating

stations and

major IPP’s

and Central

Generation

Share


Courtesy - KPTCL

11 18-Feb-12 CPRI, BANGALORE

Courtesy - KPTCL


Objectives

• Common integrated solution to cater to the network extending to the entire state of Karnataka – covering 854 Stations of Transmission, Generation and Distribution companies in the I phase.

• Integrated Solution for Energy Auditing, Energy Billing and Availability Based Tariff to meet regulator’s requirement.

• Integration of all Sub-station and Generating Station Automation systems

• Data to all ESCOMs for scheduling and monitoring

• Facilitate Integration to other “down the line” Distribution Systems of ESCOM.

BLR

144

TUM

111

MYS

152

HAS

28

BGL

237

GUL

150

RTU RTU

ALDC ALDC

DR - HUB

MCC-1 MCC-2

BLR

6 - ALDC

822 ( 400/220/110/66/33) SS

OUTLINE ARCHITECTURE - SCADA/EMS/DMS Project

Transmission SCADA


14

Features

• SCADA from all receiving stations ranging from 33kV to 400kV

• SCADA from all Major Generating stations and IPPs.

• Data from all feeders from 11 kV to 400 kV.

• Area Load Dispatch Centre for Six Transmission Zones

• Distribution Control Centre for five ESCOMs

• Up-gradation of State Load Despatch Centre

• Exclusive Control Centre for Bangalore City

• EB/EA/ABT system to perform Energy Billing, Energy Audit and

• Availability Based Tariff functions

• Sub-system to perform Open Access operations.

• Real time Energy Data Acquisition from all Interface points.

• Energy Management System and Distribution Management System

• VSAT Hub and network with leased bandwidth from INSAT 3A

• Disaster Recovery Hub


15

Functional Structure of EM Centers

Energy Management System

Data Acquisition Load Forecasting Topology Processing

State Estimator

Dispatcher Power Flow

Network Sensitivity Funct

Network Parameter

Adaptation

Security Analysis Funct

Unit Commitment

Security Dispatch

Function

Interchange Transaction

Scheduling

Voltage Control Funct

Economic Dispatch and AGC

Optimal Power flow

Supervisory Control

Logical Alarm

Sequence of Events Funct

Alarm Processor

Historical Data base

Load shedding Funct

Automatic Data collection

Safety Management

Base Functions Generation Functions Network Analysis Functions


DISTRIBUTION AUTOMATION SYSTEM (DAS)

Stages involved in Power Distribution

MV

LV

Distribution Automation

The “distribution automation” includes - automation

that is used in the planning, engineering,

construction, operation, and maintenance of the

distribution power system, including interactions with

the transmission system.

• Manuel to Automatic

• MV network is the focus

DMS Functions The typical DMS functions are i. Loss Minimization via Feeder Reconfiguration (LMFR) ii. Load Balancing via Feeder Reconfiguration (LBFR) iii. Fault Management and System Restoration (FMSR) iv. Outage Management v. Peak Management vi. Workforce Management vii. Voltage VAR control (VVC) viii. Network Connectivity Analysis (NCA) ix. State Estimation (SE) x. Load Flow Application (LFA) xi. Operation Monitor (OM) xii. Distribution Load forecasting (DLF) xiii. Distributed Planning • Operational planning • Assessing planned outages • load forecasting

System strengthening • Feeder re-configuration • Adding additional feeders • Increasing conductor size in selected segments • Reducing LT: HT ratio • Adding more distribution transformers • Load balancing on existing feeders and DTRs • Improving tail end voltage wherever required. • Revamping of sub-stations • Re-conditioning required DTRs.

Automation • RMUs on the MV network. • Sectonalisers • Auto re-closers • Fault Pass Indicators (FPI) • Communication connectivity. • DMS functions.

R

T

U

R

T

U

Primary Plant

Interface

KEY ELEMENTS of DAS

Data & Control

Pathway

Communications

Master

Station Substation

1 2

3

4 Optical Fibre,

Cable

Radio

Microwave

R

T

U

1

2 RTU

3

4

Communications

Master Station

Line

Reporting

Analysis

5

5 Control Room,

Corporate Usage

Control Room

Operators

Outage Analysis

Operational analysis,

decisions, issue controls

5


RTU

COMMUNI-

CATIONS

SCADA

DMS

User

Interface

Data

Acquisition

DMS Applications

SCADA

Functions

SCADA Platform Environment

Maintenance Management

Decision Support Systems

OMS Crew Management

GIS

Other Applications

DAS Functional/Architectural Overview

Corporate Data Accessibility and Availability


Substation No. of

interruptions

Duration of

Interruptions

S1 48 47:42:00

S2 50 23:16:15

S3 48 16:14:15

Indian utilities statistics

Example Failure Rates

Overhead Failure Rates

Voltage Circuit

km

Failures

Over

5 Years

Failures

Per km

Per Year

12kV

Main 309 190 0.123

Lateral 217 201 0.185

4kV

Main 241 111 0.092

Lateral 161 70 0.087

Underground Failure Rates

Voltage Circuit

km

Failures

Over

5 Years

Failures

Per km

Per Year

12kV

XLPE 360 33 0.018

EPR 116 9 0.016

PILC 231 64 0.055

PE 242 13 0.011

4kV

XLPE 28 1 0.007

EPR 12 2 0.033

PILC 160 30 0.038

PE 10 0 0.000


Example Causes of Failure Equipment Failures

(Resulting In Sustained Outages)Average (1996-2001)

0

20

40

60

80

100

120

140

160

Equ

ipm

ent F

ailu

re

Unk

nown

Act

ivity

/Fore

ign

Obj

ect

Veg

etat

ion

Wea

ther

Dis

trib

utio

n Supp

ly F

ailu

re

Ele

ctrica

l Ove

rloa

d

Oper

atin

g Error

Oth

er C

ircu

it

Impr

oper

Cons

truct

ion

Nu

mb

er

of

Su

sta

ine

d O

uta

ge

s

6 Year Average


Outage Management System

• Automatically infers fault location based on customer trouble calls or other indications

• Shows fault location on geographical display of power system so crews can be dispatched immediately to this location

• Displays can be used to show crew positions and reflect repair status as switches are opened and closed

• Tracks number of interrupted customers and corresponding outage durations

Reduces repair times, keeps customers better informed,

and provides more accurate reliability data!


Automation Philosophy

Circuit Breaker

R/S feeder R/S feeder

Remote operation to close switch

Additional network restored, total time 11-18 mins

Circuit Breaker


Normally open point

Automated RMU / DT with FPI

Circuit Breaker


Normally open point

FPI indicates passage of fault current

CB Trips

Circuit Breaker


Normally open point

Remote Operation of RMU Switch & Partial Restoration of supply – typically 1-2 mins

After Automation ( Average time to restore Power Supply to healthy section 1-2 Minutes)


Impact of Automation System

Power Restored

to Customers on

Healthy Sections

of FeederFault

Occurs

Customer

Reports

Outage

Travel Time

Fault

Located

Investigation

& Patrol TimeTime to Perform

Manual Switching Repair Time

Feeder

Back to

Normal

5 – 10

minutes

15 – 20

minutes

10 - 15

minutes

45 – 75

minutes

15 – 30

minutes

1 - 4

Hours

Power Restored

to Customers on

Healthy Sections

of FeederFault

Occurs

Customer

Reports

Outage

Travel Time

Fault

Located

Investigation



Feeder

Back to

Normal

5 – 10

minutes

15 – 20

minutes

10 - 15

minutes

45 – 75

minutes

15 – 30

minutes

1 - 4

Hours

Fault

Occurs

Customer

Reports

Outage

Travel Time

Fault

Located

Investigation



Feeder

Back to

Normal

5 – 10

minutes

15 – 20

minutes

10 - 15

minutes

45 – 75

minutes

15 – 30

minutes

1 - 4

Hours

Without Automation

With Automation

minutes Hoursminutesminutes Hoursminutesminutes Hoursminutes1 – 2

minutes

1 – 2

minutes

1 – 2

minutes

Field

Crews

On- Scene

15 – 30

Feeder

Back to

Normal

Power Restored

to Customers on

Healthy Sections

of Feeder

Travel Time Repair Time

1 - 4 5 - 10

Patrol

Time

Customer

Reports

Outage

Fault

Occurs

Field

Crews

On- Scene

15 – 30

Feeder

Back to

Normal

Power Restored

to Customers on

Healthy Sections

of Feeder


1 - 4 5 - 10

Patrol

Time

Customer

Reports

Outage

Fault

Occurs

Field

Crews

On- Scene

15 – 30

Feeder

Back to

Normal

Power Restored

to Customers on

Healthy Sections

of Feeder


1 - 4 5 - 10

Patrol

Time

Customer

Reports

Outage

Fault

Occurs


Future

State

Analysis

Crew Management

Outage

Management

Outage Analysis

Outage Reporting

IVR

Reports and

History

Operational

Diagrams

Switching

Management Switching

Planning

Asset

Maintenance CIS

SCADA

Network

Operational

Model

NOM

Updates to

Network Model

and Diagrams

Calls

Planning ERP, GIS

Corporate

Asset Data

and

Model

Design

r/t state r/t state

Current State

Analysis

(Incorporates Load

Modelling and

Network Analysis

Typical Distribution Control Room

Environment


Future

State

Analysis

Crew Management

Outage

Management

Outage Analysis

Outage Reporting

IVR

Reports and

History

Operational

Diagrams

Switching

Management Switching

Planning

Asset

Maintenance CIS

SCADA

Network

Operational

Model

NOM

Updates to

Network Model

and Diagrams

Calls

Planning ERP, GIS

Corporate

Asset Data

and

Model

Design

r/t state r/t state

Current State

Analysis

(Incorporates Load

Modelling and

Network Analysis

Typical Distribution Control Room

Environment

DAS


Reliability Performance Indices

• With moves toward deregulation and open competition, access to accurate and timely outage information is critical in order to maximize operational efficiency, minimize customer complaints, and maintain electric system reliability.

• In this respect, it is common practice to track and benchmark reliability using standard performance indices such as CAIDI, SAIFI, and SAIDI.

• These indices serve as valuable tools to compare utility reliability performance, but care must be taken to ensure they are being calculated in the same manner.


Index Definitions • System Average Interruption Frequency Index

• System Average Interruption Duration Index

• Customer Average Interruption Duration Index

Served Customers ofNumber Total

onsInterruptiCustomer ofNumber TotalSAIFI

Served Customers ofNumber Total

Durationson InterruptiCustomer SAIDI

onsInterruptiCustomer ofNumber Total

Durationson InterruptiCustomer CAIDI

Interruptions/Customer/Yr

Minutes/Customer/Yr

Minutes/Interruption/Yr

AIL

Crew

Savings

Man

Power

Savings

Fmas

Savings

Scada

Scada

Cost

Savings in

Power @ 40

% LF

Pay Back

Period(

Yrs)

Before After Before After Before After Before After

0 3.2 3.2 12.4 12.4 192000 192000 105 105 0 0 0 0 0 0

1 3.2 0.8 12.4 2.95 192000 48000 105 26 3365.4 561 97.6 759.5 6.1236 0.2

2 3.2 3.2 12.4 7.6 192000 192000 105 105 0 561 97.6 872 3.1104 1.87

3 3.2 1.8 12.4 8.25 192000 108000 105 59 1959.6 561 97.6 872 2.6892 0.36

4 3.2 0.6 12.4 2.7 192000 36000 105 19 3663.6 561 97.6 1172 6.2856 0.29

5 3.2 0.6 12.4 1.5 192000 36000 105 19 3663.6 561.00 97.6 1584.5 7.0632 0.39

SAIFI SAIDI

No. of Permanent

Faults No. of VehiclesConclusions


Example of Automated GOS


Example of Automated Load Break Switches/Line Reclosers

SF6 LBS

Vacuum LBS

Air-Break LBS

Line Recloser


Example of RMU (Pad-Mounted Switches)

Generally, if not automation ready, can be retro-fit with motor

or solenoid operating mechanism


Substation Automation


SS Architecture - wired


STATION LEVEL

BAY LEVEL

PROCESS LEVEL

SS Architecture – Networked – IEC 61850


PROCESS LEVEL

BAY LEVEL

STATION LEVEL

ETHERNET

IEC 61850 - ARCHITECTURE


Substation Bus – Ethernet – OFC – 100/1000 Mbps

Process Bus – Ethernet – OFC – 100/1000 Mbps

IED

(Relay) IED

(BCU)

IED

(METER)

HMI Gateway

MU MU MU LEGACY IED

GOOSE

TO RCC

INTEROPERABLE

IEC 61850 – SALIENT FEATURES


1. Freedom to allocate function to devices

2. Interoperability – IEDs of different mfrs can co-exist and exchange

info.

3. One or more logical node in a physical device

4. Sampled values of Voltage and Current exchange

5. High speed IED to IED communication – [GOOSE]

6. Interface to legacy system

MACRO - MICRO


LOGICAL DEVICE

LOGICAL NODE

DATA&OBJECTS

M/CT/ST

ATTRIBUTE

U/MF/SIGN

PHYSICAL DEVICE

Smart Grid


THE ENERGY SECURITY

• Demand for energy – all forms - unsustainable

• KYOTO PROTOCOL • Climate change • Global warming – restrict GREEN house gas • CO2 - emissions

• Need at least 50% more energy in 2030.

CPRI

47 CPRI, BANGALORE

Fossil Fuel

Coal

Oil

18-Feb-12

THE KEY DRIVERS CPRI

48 CPRI, BANGALORE

Need for more energy

Increased usage of renewable energy resources

Sustainability

Competitive energy prices

Security of supply

Ageing infrastructure and workforce

18-Feb-12

Energy consumption 3.4% of global level

Demand for energy 3.6% per annum

Power statistics - India

Installed capacity as of September 2010.

Sector MW %age State Sector 80,844.12 52.5 Central Sector 51,867.63 34.0 Private Sector 32,124.05 13.5 Total 1,64,835.80 Per capita usage 612 kwh Energy = -12.1% Peak Demand = - 10.6%

CPRI

Peak periods

DEM

AN

D

• Balance Demand with Supply • Reduce Losses • Customer participation in Supply – DSM / DR • Time of USE - TOU • Green initiatives - RE

peak shaving

Distribution – smart grid

0 24 Time

peak shifting

50 CPRI, BANGALORE

DG

DSM/DR

18-Feb-12

SMART GRID

51

DG – Distributed Generation DR – Demand Response

Integrated Intelligence

Network I2N

Courtesy - IEEE

A reform process which aims at optimally utilising the available energy with demand

CPRI

51 CPRI, BANGALORE 18-Feb-12

1. Self-Healing and Adaptive – Rapidly detects, re-configures and restores power supply.

2. Interactive with consumers and markets - Motivates and includes the consumer and stakeholders.

3. Optimized to make best use of resources and equipment - Optimizes assets and operates efficiently.

4. Predictive rather than reactive – the system operation can be planned to avoid emergencies.

5. Distributed Generation - Accommodates all generation and storage options

CPRI Characteristics of SG


“an automated, widely distributed energy delivery network characterized by a two-way flow of electricity and information, capable of monitoring and responding to changes in everything from power plants to customer preferences to individual appliances.”

Smart Grid Vision Definition


Smart Grid Challenges

• Financial Resources The regulators will require extensive proof before authorizing major investments based heavily on societal benefits.

• Government Support The industry may not have the financial capacity to fund new technologies without the aid of government programs to provide incentives to invest.

• Compatible Equipment Some older equipment must be replaced as it cannot be retrofitted to be compatible with smart grid technologies. This may present a problem for utilities and regulators since keeping equipment beyond its depreciated life minimizes the capital cost to consumers. Early retirement of equipment may become an issue.


Smart Grid Challenges

• Speed of Technology Development The solar , the basement fuel cell, and the chimney wind generator were predicted 50 years ago as an integral part of the home of the future.

• Policy and Regulation The state financing the project may not always be the one benefiting most from it. Unless an attractive return on smart grid investments is encouraged, utilities will remain reluctant to invest in new technologies.

• Cooperation The challenge for diverse utilities will be the cooperation needed to install critical circuit ties and freely exchange information to implement smart grid concepts.


The Functionalities

1. AMI 2. Smart Distribution 4. Smart Pricing

5. Demand Control

6. Building / Home automation

7. Renewable Integration

8. Plug in Electric Vehicle - Bay

9. Condition Based Maintenance


consumers [smart meters]

Power network & apparatus

SG Control Center

DG

Two way communication

Smart Grid Control Scheme CPRI

Two way communication

MDM CP ANALYTICS OMS PM

DA SA CBM

AMI SMART METERS HAN

SOLAR PV WIND BIO MASS 57 CPRI, BANGALORE 18-Feb-12

IT LAYER

COMMUNICATION LAYER

NETWORK LAYER

Typical System Architecture CPRI


Metering



Advanced Metering Infrastructure (AMI) AMI and its role: The AMI is the nerve center of any smart grid implementation. AMI constitute Smart meters at consumer premises. Two way communication network between CC and end points. MDAS that will act as Front end to field devices and MDMS IT system comprising of HW and SW running MDMS located at the SGMC. The role of AMI is vital and would facilitate Periodic flow of customer meter data and network data in to the data base. Disseminate DSM / DR programs Facilitate MDM Customer empowerment through consumer portal

Why Immediate Attention?

• Meter data is becoming vital part in deciding many of the performance and planning parameters of utilities.

• Many of utilities are looking for automation to manage huge amount useful data generated from meters and other sources of grid/network.

• AMR is becoming part of DA/DSM/SCADA leading to AMI / Smart metering solution.

• AMR / AMI is becoming best tool to check AT & C losses and control / detect pilferages.


Smart Meter – The Notion

• An intelligent device which enables a customer to participate in the utilities initiatives for energy management.

• The initiatives are put forth by utility through its policies and functions.

• Lead to Smart metering - Not only collecting information but also sending information.


Smart Metering

Typical functions are:

• Interval meter data (load profile.

• Meter reading

• Meter management (reduction, disconnection, demand management, etc).

• Measurement of consumption and generation by distributed units.


Smart Metering

• Meter parameterisation such as tariff structures, contractual power, meter interval, etc.

• Message transfer from market players to the customer - price signals.

• Information display on the meter and / or communication port for external display

• Power quality measurement (incl. Continuity of supply and voltage quality)..



METERS THAT MATTER HOST

A BJ / KJ

HT

M4

M3 M1

M2

LT

HT

D C&I

OTHERS

SS Meters – 11/33/66/110/220/400 kV

BOUNDARY / BANK METERS - ABT

DTR

DATA

ROUTING NETWORK

FEP

FEP

FEP

Metering management

• It is crucial that the party responsible for collecting and administrating meter data makes data accessible to all other authorised market players in a non-discriminatory way.

• If the customer is expected to react to price signals, actual demand etc...then easy access to meter data, for instance on a display, is needed.


• Automated meter reading (AMR)

• Meter Date Management (MDM)

Need for protocol


APPLICATION

LINK LAYERS

PHYSICAL LAYER

APPLICATION

LINK LAYERS

PHYSICAL LAYER

PSTN PLC RF TCP/IP CELLULAR

1. No common meter reading protocol

2. Many manufacturers – many communication protocols.

3. Non availability of protocol information

4. Integration issues - different make meters at the field level.


AMR impediments

THE APPROACH • Homogeneity at meter end

• Accessibility at all times

• Interoperability


HOST

METER WITH STANDARD PROTOCOL

Choose OPEN PROTOCOL - A General practice


The IEC 62056 is an open protocol exclusively evolved for Metering purpose. It operates at meter level. A wide range of data types can be read either selectively or in groups. The parameters are identified through unique codes. The protocol can work with many common communication medium. The protocol implementation can be verified for conformance with the dedicated test tool. India has been aligning with IEC for standardization. In the present effort to bring in uniform protocol and based on the relative merits and demerits, IEC 62056 protocol would become the natural choice for metering purposes in India.

Open Protocols


IEC 62056 (dlms) FEATURES

OBJECT MODELLING - COmpanion Specification for Energy Metering

[COSEM]

DATA IDENTIFICATION – Object Identification System [OBIS] & IC

MEASUREMENT COMPUTATION COMMUNICATION

METER

MANDATORY OBJECTS

ADDITIONAL OBJECTS

INSTANTANEOUS VALUES

PROFILES

TARIFF READINGS

POWER QUALITY PARAMETERS

AND OTHERS

ADOPTED BY IEC


The smart meters shall have the following minimum features:

1. Measure and Compute electrical parameters.

2. Store and communicate requested data as per programmed interval.

3. Detect, resolve abnormal & tamper events and store the same

4. Inbuilt memory to store all relevant meter data, events for a required period.

5. Meter communication protocol shall be as per open standard.

6. Options for both Prepaid and postpaid metering.

7. Shall be configurable remotely.

8. Interface to a Home Display Unit

9. Support remote firmware upgrade

10. Support remote load management

11. Load Reconnect / Disconnect switch

• Steady state values - Instantaneous

• Dynamic values - Profiles

• Harmonics - Power Quality

• Import / Export - Four Quadrant

• Event recording / reporting

• Time Stamping

• Unit & Scaler representation

• Unique identification codes - OBIS

• Country / Manufacturer specific codes

• In built support for common communication profiles

• Access and Data Security

• Interoperable


IEC 62056 – DLMS / COSEM –A Overview

1. Power line communication – Broadband

– Narrowband

2. Low power RF – Mesh networks - Zigbee

75 CPRI, BANGALORE

Smart meters - communication

18-Feb-12

HAN Architecture

DCU

GSM ZGW

ZC

ZC

ZC

ZC

Geyser

AC

Room Heater

Fridge

HDU Contact

or

Contactor

Contactor

Contactor

1Ø / 3Ø AC 77 CPRI, BANGALORE 18-Feb-12

Zigbee Zigbee is a new wireless technology built on the IEEE 802.15.4 networking standard for wireless personal area networks (WPANs). ZigBee is targeted at RF applications that require low data rate low power low cost Worldwide ZigBee operates in 2.4 GHz, the ISM radio bands which do not require license. The composite IEEE standard (Physical and Mac layers) and Zigbee (network and application layers) standard has enabled enormous applications for home automation, wireless sensors, automatic meter reading etc.


Device types

The Zigbee system is a network of three different types of generic devices namely ZigBee coordinator(ZC), ZigBee Router (ZR) ZigBee End Device (ZED). ZC - Root of the network tree , generally one per network. Store information about the network Monitor performance Configure parameters. ZR - Function as a router / intermediate router Passing data from other devices Stretching the reach. ZED - Only discharge designated function Example - controlling a light. ZED can talk to ZC or ZR Cannot relay data from other devices.

CPRI


Topology

Wireless Control That Simply Works

ZigBee Coordinator

ZigBee Router

ZigBee End Device

Star

Mesh

Cluster Tree

The “Topology” is the configuration of the hardware components and how the data is transmitted through that configuration. The Zigbee networking supports three topologies - Star, Mesh and Cluster Tree.

CPRI


BPLC URBAN / RURAL NETWORK

LV / MV DATA RATE > 10 Mbps

Sub station

DTR

DTR

ISP NODE

DSL INTERNET

CLOUD

MCC

11 kV


FOC + PLC - COMBI FOR POWER SECTOR AND INTERNET

FIBRE BACK BONE

CPE

SS

CPE

DTR

CPEs BB-ROUTER

AMR LV

10

HOST

HT

MV

DSL

DSL

50

DSL


Thank you

varun @ cpri.in


automation in scada, substation & metering

Documents