As you have been studying, the thrust of distribution reforms has been on improving distribution by reducing losses and theft. You have learnt about the potential of IT for improving operational efficiency and reducing theft in previous Unit.This involves
• acquiring and managing detailed data on all aspects of power distribution including the consumption by type of user, location, time, etc.,
• metering at the consumer-end and the Distribution Transformers (DTRs),
• location of various network components such as substations, feeders, DTRs, lines and cables, etc.
Measuring data for revenue purposes involves capturing real energy, kWh, reactive energy, kVAR, and maximum demand data. The data that can tell both the supplier and the consumer about the quality and reliability of the power supply includes the following:
• voltage and current magnitudes and phase angles, along with time of maxima and minima,
• harmonic analysis,
• event recording triggered by definable set points,
• waveform capture,
• data logging,
• sequence of event reporting.
This data allows companies to analyze, diagnose and mitigate a spectrum of disturbances. It also helps in monitoring the flow of energy through the network for proper audit and accounting. Fig. shows a generic IT system for power distribution downstream from the substation level for acquiring and processing this information.The system shown in Fig. involves transmitting information over the power lines themselves using Power Line Carrier (PLC) communications. Of course, other networking options could be used, such as modems or wireless.PLC typically requires devices at either end that take signals on/off from the grid (modems, essentially).
At the consumer end (or on the pole, if required), this can be integrated with the meter. This system typically involves aggregating data from consumers,such as at the Distribution Transformers (DTR). One major use of this system might be for automated meter reading, which has been seen worldwide as attractive given the high costs of Customer Relations Management (including meter reading).
• acquiring and managing detailed data on all aspects of power distribution including the consumption by type of user, location, time, etc.,
• metering at the consumer-end and the Distribution Transformers (DTRs),
• location of various network components such as substations, feeders, DTRs, lines and cables, etc.
Measuring data for revenue purposes involves capturing real energy, kWh, reactive energy, kVAR, and maximum demand data. The data that can tell both the supplier and the consumer about the quality and reliability of the power supply includes the following:
• voltage and current magnitudes and phase angles, along with time of maxima and minima,
• harmonic analysis,
• event recording triggered by definable set points,
• waveform capture,
• data logging,
• sequence of event reporting.
This data allows companies to analyze, diagnose and mitigate a spectrum of disturbances. It also helps in monitoring the flow of energy through the network for proper audit and accounting. Fig. shows a generic IT system for power distribution downstream from the substation level for acquiring and processing this information.The system shown in Fig. involves transmitting information over the power lines themselves using Power Line Carrier (PLC) communications. Of course, other networking options could be used, such as modems or wireless.PLC typically requires devices at either end that take signals on/off from the grid (modems, essentially).
At the consumer end (or on the pole, if required), this can be integrated with the meter. This system typically involves aggregating data from consumers,such as at the Distribution Transformers (DTR). One major use of this system might be for automated meter reading, which has been seen worldwide as attractive given the high costs of Customer Relations Management (including meter reading).
 | |||
| Generic IT enabled Power Distribution System |
Source: What IT Can and Cannot do for the Power Sector and Distribution in India: Link to Reforms, Incentives, and Management by Rahul Tongia presented at the GreenPower Conference in New Delhi, October 2003 you know that the HT consumers are the prime source of revenue for distribution utilities. Every utility therefore wants to ensure that all HT consumers are read properly and any leakage with respect to HT consumers is checked. Since the number of HT consumers in most of the Indian utilities are relatively small vis-Ã -vis their total consumer base, efforts have been made by the utilities to remotely read meters of HT consumers.Some utilities have also been able to integrate Remote Meter Reading with the billing process which has further streamlined their operations.
Today, many ERCs have mandated metering at the DTR level. Thus, many utilities are using AMR and RMR as well as metering of Distribution Transformers for reduction in theft and implementing an efficient energy accounting system as mandated by the Regulatory Commissions. However,the metering devices being used today are meant more for energy auditing purposes, and not for control or real-time operations. Communications are typically for once a month reconciliation. Different technologies such as the following have been used for getting the data from the meter to the control units:
• Public Switched Telephone Network (PSTN),
• Global System for Mobile Communications (GSM),
• Radio Frequency (RF), and
•Code Division Multiple Access (CDMA).
The Public Switched Telephone Network (PSTN) and Global System for Mobile Communications (GSM) are the most popular ones among the utilities. The Radio Frequency (RF) based communication has problems of range, while Code Division Multiple Access (CDMA) based communication has not been very successful in the country as the CDMA modems are not readily available in the market. But as you may know, the possibility of implementing Availability Based Tariff (ABT) implies an order of 100,000 or 35,000 readings per node per year. Only a dedicated IT and communications system would prove to be cost-effective.There are significant benefits of designing a system that includes a real-time (or near real-time) data acquisition, data communication and control at the consumer interface and/or DTR level. We present a comparison of different metering/IT technologies in terms of their capabilities in Table.
Today, many ERCs have mandated metering at the DTR level. Thus, many utilities are using AMR and RMR as well as metering of Distribution Transformers for reduction in theft and implementing an efficient energy accounting system as mandated by the Regulatory Commissions. However,the metering devices being used today are meant more for energy auditing purposes, and not for control or real-time operations. Communications are typically for once a month reconciliation. Different technologies such as the following have been used for getting the data from the meter to the control units:
• Public Switched Telephone Network (PSTN),
• Global System for Mobile Communications (GSM),
• Radio Frequency (RF), and
•Code Division Multiple Access (CDMA).
The Public Switched Telephone Network (PSTN) and Global System for Mobile Communications (GSM) are the most popular ones among the utilities. The Radio Frequency (RF) based communication has problems of range, while Code Division Multiple Access (CDMA) based communication has not been very successful in the country as the CDMA modems are not readily available in the market. But as you may know, the possibility of implementing Availability Based Tariff (ABT) implies an order of 100,000 or 35,000 readings per node per year. Only a dedicated IT and communications system would prove to be cost-effective.There are significant benefits of designing a system that includes a real-time (or near real-time) data acquisition, data communication and control at the consumer interface and/or DTR level. We present a comparison of different metering/IT technologies in terms of their capabilities in Table.
 |
| IT Technologies in Terms of Their Capabilities |
Let us now find out what the systemic requirements for this kind of an IT application are.
Hardware and Software Requirements
The following conditions must be fulfilled before implementing the Automatic Meter based data acquisition system:
• The electromechanical or static type of meters without data downloading facility (in feeders, distribution transformers or high value
consumers), should be replaced with static meters having data downloading facility to enable remote metering.
• The feeder meters provided at substations should be Modbus compliant and fitted with RS 485 ports and at Distribution Transformers,
HT and High revenue LT Consumer locations with RS 232 ports in addition to normal optical ports. (Modbus is a communication protocol, designed by Modicon for use with its programmable logic controllers (PLCs).)
• The billing should be computerized so that the data logging software can interact with billing software to capture billing and energy consumption data of all LT Consumers, which are not AMR enabled.
• GIS Based consumer indexing and asset mapping should be in place, so that data logging software can interact with GIS database to capture information of consumers connected with a particular Distribution Transformer (DT) for the purpose of DT wise energy audit.
• Meter data structure or drivers provided by manufacturers of different makes of meters should be made available for translating meter data into standardized common data structure for existing Feeder Meters,DT Meters and Consumer Meters, so as to make the inter-operability of different makes of meters functional with standard software.The hardware requirements for an online real time data acquisition system are given in Box.
Box : Hardware Requirement for an Online Real Time Data Acquisition System
• Static meters with Modbus compliant RS 485 port at substations.
• Data converter unit at substation.
• PC with data collecting Software at substation (optional).
• Meter with RS 232 Port at DT and Consumer Locations.
• Data acquisition server at central location.
• Modems (PSTN/GSM/CDMA) at substation and other meter locations.
The Software/Application Platform requirements are as follows:
• The system architecture should be modular so that only the required modules need to be installed at any given location.
• The software system deployment and implementation should be flexible and may include installing the software at various locations like substations and central office.
• The software should be compatible with RDBMS and preferably the utilities’ own database should be utilised for this purpose.
• The software should have GUI front-end and menu driven functions for automatic data collection from meters connected locally or in remote,locations, through modem communication, periodic data uploading through modem on central monitoring system. The software must be able to validate uploaded data.• The software should be capable of collecting data on a common standardized format from meters of various manufacturers. The data logging software package should be able to integrate, extract and analyze data of different makes of meters.
• The software should be designed with multi-tier (N-tier) design methodology. It should have distinct tiers representing the client/business/database layers, etc.
• The software should be able to communicate with the other business process applications of the utilities and should be able to exchange data as and when necessary.
• Databank/database should be maintained for the repository of the data collected and processed from meters, including interval usage data, event logs and outage history, as well as derived data such as aggregations and asset performance indicators like load factor and load duration curves.
• Software should support selective monitoring of important summarized data at user-defined intervals that would aid in decision-making for distribution operation and planning actions.
• Software should be able to display SLD schematics for important network areas.
• The software should be able to represent graphically the data collected over a timeline.
• The system should be able to check energy balance between HV side and LV side of any substation, 11 kV feeder flow against consumption of HT consumers and DTs in the feeder, to add consumptions of all the consumers connected to a particular DT and the consumptions of all the DTs in an 11 kV feeder. The necessary data in this regard would be available from the Customer indexing and asset coding database and billing database.
• The system should have the ability to calculate by proper algorithm the allowable technical losses in the system from the power flow data and network data provided to the system.
• The system should be able to calculate the estimated technical losses and commercial losses in every part of the network.
Deliverables
The Deliverables for Metering, Data Acquisition and Management are as follows:
• Real time data acquisition from meters.
• Historical time stamped data acquisition from meters.
• Supervisory function, i.e., processing, monitoring, analysis and diagnostics.
• Data exchange and storage facility.
• Report generation and reporting including user defined customization, e.g., calculation of feeder/DT performance statistics, energy balancing and auditing, etc.
• Alarm and event listing, limit value violations, reporting of critical events e.g., no communication with meter, power failure, etc.
• Facility to enter manual readings and associated data for taking care of meter change, but only with appropriate user identification, security and audit trial.
• Facility for storing acquired data, both analogue and digital form in database and display of single line diagram of the entire electrical network.
• Support for load forecasting and system planning on short, medium and long term basis.
We now present a case study demonstrating the use of IT for a variety of applications by a power utility including energy accounting and reduction in non-technical losses.
Case Study of MSEB, Thane District
CMC has developed a “Power Desk”, an integrated consumer relationship management and energy accounting system, for efficient management
control of power utilities. Power Desk has several value-added features, which lead to reduction of non-technical losses and better consumer services.
FEATURES
• An integrated solution for consumer-related business processes and energy accounting;
• Includes a mechanism for reducing non-technical losses;
• Targeted for implementation at the billing unit level;
• Focuses on independent profit centre; and
• A solution with a consumer-centric approach.
SYSTEM MODULES
• Customer Relationship Management.
• MIS for Consumer billing.
• Consumer registration and processing application.
• Application database on consumer.
• Management the registration process.
• Facilitatation of the registration of consumer billing complaints.
• Providing services to Consumer.
• Tracking of consumer complaints and applications.
• Consumer billing.• Bill accounting
• Reports for management
MIS FOR UTILITIES
Network connectivity data maintenance for:
• Administrative areas,
• Substations and feeders,
• Distribution transformer centres,
• Consumer master,
• Single-line diagram construction utility,
• Energy accounting,
• Energy input logging,
• Facility to enter or import data for HT consumers,
• Calculation of energy losses at feeder and billing unit level,
• Segregation of technical and non-technical losses,
• Facility to compute consumption for un-metered consumers,
• Energy losses analysis module,
• Energy meters tracking system,
• Interruptions analysis for better maintenance planning,
• Technical architecture, hardware and software platforms,
• Based on client-server architecture, and
• Runs on any open system platform.
HARDWARE CONFIGURATION
Intel P IV, Windows 2000 server
SYSTEM SPECIFICATIONS
Operating system: Windows 2000
RDBMS: Oracle, Sybase
GUI client
STRENGTHS
• Improves the financial performance of the utility.
• Provides a mechanism for reduction in losses.
• Improves efficiency of customer relationship management.
• Improves the level of customer satisfaction.
• Efficient consumer billing and complaint handling system.
• Reduces interruptions to the consumer by better maintenance planning.
• Efficient consumer servicing.
• Provides better administrative control.
SECURITY AND HOUSEKEEPING FEATURES
• Audit reports.
• Defining users.
• Dynamic report engine.
• View and print predefined reports.
• Export output to print file.
• Thematic query facility.
• Basic load flow.
BENEFITS
• Online availability of consumer-related data.
• Flexible billing cycles.
• Fewer consumers billed on average basis.
• Timely billing to consumers.
• Improved revenue and cash flow.
• Process bills of consumers as per reading on the same day.
• Reduces the time required for realization of bills.
• Better receivables management.
• Account for receipts on the same day.
• Enables availability of an online arrears list.
• Enables better strike rate and improvement in collection of arrears.
• Better administrative control of consumer-related business process.
• Tracking of consumer applications.
• Meter-tracking module.
• Inspection report logging facility.
• Security policy enables definition of roles of each employee.
• Data is logged with user ID (identification) and time stamp.
• MIS reports for data authenticity investigations.
• MIS reports for employee-wise meter reading data.
• Better consumer servicing.
• Processing of consumer requests for meter changes, change of name, disconnections, etc.
• Consumer registration module.
• Consumer information module.• Better maintenance planning
• Logging of feeder interruptions with the category
• Maintenance planning based on reason codes
In this context, you may also like to learn about Supervisory Control and Data Acquisition (SCADA).
Supervisory Control and Data Acquisition (SCADA) SCADA involves networking of a group of substations (especially in Metros and large towns) for data collection in respect of all equipment installed at a host station. SCADA systems are developed using a host of enabling core technologies such as those related to Data Communications, Centralized and Distributed Databases, Decision Support, Real-time Computing, Power System Analysis,Geographical Information Processing, Graphics and Multimedia, Distributed Process Control, Simulation and Forecasting and Enterprise Resource Planning (ERP). Some of these Information Systems such as Management Information Systems (MIS) and Maintenance Management Systems (MMS) are generic in structure for all industries, while being specific to a power utility in some functional aspects.
SCADA is an effective tool for remote sensing of system parameters. The distribution system can be monitored on a real time basis and also controlled by issuing commands to remote stations where RTUs are located. The aim of the system is effective load management of the distribution system to improve reliability and efficiency of supply.Since the process is on-line, supply conditions given by the instant loading and voltage profile are effectively monitored, daily and monthly data are readily aggregated, and the energy flow is easily tracked to individual feeders. An immediate benefit is the ability to make instant corrections to network imbalances by way of remote operation of transformer tap-changers, feeder switching, etc., at unmanned substations, thereby optimising workforce deployment and eliminating the monotonous task of manual logging.
Another advantage of SCADA is that voluminous data can be stored and retrieved to generate both active and reactive power load profiles. Such data are available in tabular as well as graphical mode. SCADA also offers electrical parameters with greater accuracy.
The system comprises
– Control Centre equipment,
– Application software,
– Distribution Management Software,
– Communication System,
– RTUs for field data acquisition,
– UPS, etc.
A typical SCADA scheme installed in a typical 33/11 kV is depicted in Fig. where an optical fibre cable has been laid for setting up the data communication channel to interlink their substations with a central control room and set up both point-to-point and point-to-multi-point connectivity. These are:
• optical fibre (OF)
• leased line telephone,
• radio (dedicated) link,
• radio (cellular link), and
•power line carrier (Fig.).
Hardware and Software Requirements
The following conditions must be fulfilled before implementing the Automatic Meter based data acquisition system:
• The electromechanical or static type of meters without data downloading facility (in feeders, distribution transformers or high value
consumers), should be replaced with static meters having data downloading facility to enable remote metering.
• The feeder meters provided at substations should be Modbus compliant and fitted with RS 485 ports and at Distribution Transformers,
HT and High revenue LT Consumer locations with RS 232 ports in addition to normal optical ports. (Modbus is a communication protocol, designed by Modicon for use with its programmable logic controllers (PLCs).)
• The billing should be computerized so that the data logging software can interact with billing software to capture billing and energy consumption data of all LT Consumers, which are not AMR enabled.
• GIS Based consumer indexing and asset mapping should be in place, so that data logging software can interact with GIS database to capture information of consumers connected with a particular Distribution Transformer (DT) for the purpose of DT wise energy audit.
• Meter data structure or drivers provided by manufacturers of different makes of meters should be made available for translating meter data into standardized common data structure for existing Feeder Meters,DT Meters and Consumer Meters, so as to make the inter-operability of different makes of meters functional with standard software.The hardware requirements for an online real time data acquisition system are given in Box.
Box : Hardware Requirement for an Online Real Time Data Acquisition System
• Static meters with Modbus compliant RS 485 port at substations.
• Data converter unit at substation.
• PC with data collecting Software at substation (optional).
• Meter with RS 232 Port at DT and Consumer Locations.
• Data acquisition server at central location.
• Modems (PSTN/GSM/CDMA) at substation and other meter locations.
The Software/Application Platform requirements are as follows:
• The system architecture should be modular so that only the required modules need to be installed at any given location.
• The software system deployment and implementation should be flexible and may include installing the software at various locations like substations and central office.
• The software should be compatible with RDBMS and preferably the utilities’ own database should be utilised for this purpose.
• The software should have GUI front-end and menu driven functions for automatic data collection from meters connected locally or in remote,locations, through modem communication, periodic data uploading through modem on central monitoring system. The software must be able to validate uploaded data.• The software should be capable of collecting data on a common standardized format from meters of various manufacturers. The data logging software package should be able to integrate, extract and analyze data of different makes of meters.
• The software should be designed with multi-tier (N-tier) design methodology. It should have distinct tiers representing the client/business/database layers, etc.
• The software should be able to communicate with the other business process applications of the utilities and should be able to exchange data as and when necessary.
• Databank/database should be maintained for the repository of the data collected and processed from meters, including interval usage data, event logs and outage history, as well as derived data such as aggregations and asset performance indicators like load factor and load duration curves.
• Software should support selective monitoring of important summarized data at user-defined intervals that would aid in decision-making for distribution operation and planning actions.
• Software should be able to display SLD schematics for important network areas.
• The software should be able to represent graphically the data collected over a timeline.
• The system should be able to check energy balance between HV side and LV side of any substation, 11 kV feeder flow against consumption of HT consumers and DTs in the feeder, to add consumptions of all the consumers connected to a particular DT and the consumptions of all the DTs in an 11 kV feeder. The necessary data in this regard would be available from the Customer indexing and asset coding database and billing database.
• The system should have the ability to calculate by proper algorithm the allowable technical losses in the system from the power flow data and network data provided to the system.
• The system should be able to calculate the estimated technical losses and commercial losses in every part of the network.
Deliverables
The Deliverables for Metering, Data Acquisition and Management are as follows:
• Real time data acquisition from meters.
• Historical time stamped data acquisition from meters.
• Supervisory function, i.e., processing, monitoring, analysis and diagnostics.
• Data exchange and storage facility.
• Report generation and reporting including user defined customization, e.g., calculation of feeder/DT performance statistics, energy balancing and auditing, etc.
• Alarm and event listing, limit value violations, reporting of critical events e.g., no communication with meter, power failure, etc.
• Facility to enter manual readings and associated data for taking care of meter change, but only with appropriate user identification, security and audit trial.
• Facility for storing acquired data, both analogue and digital form in database and display of single line diagram of the entire electrical network.
• Support for load forecasting and system planning on short, medium and long term basis.
We now present a case study demonstrating the use of IT for a variety of applications by a power utility including energy accounting and reduction in non-technical losses.
Case Study of MSEB, Thane District
CMC has developed a “Power Desk”, an integrated consumer relationship management and energy accounting system, for efficient management
control of power utilities. Power Desk has several value-added features, which lead to reduction of non-technical losses and better consumer services.
FEATURES
• An integrated solution for consumer-related business processes and energy accounting;
• Includes a mechanism for reducing non-technical losses;
• Targeted for implementation at the billing unit level;
• Focuses on independent profit centre; and
• A solution with a consumer-centric approach.
SYSTEM MODULES
• Customer Relationship Management.
• MIS for Consumer billing.
• Consumer registration and processing application.
• Application database on consumer.
• Management the registration process.
• Facilitatation of the registration of consumer billing complaints.
• Providing services to Consumer.
• Tracking of consumer complaints and applications.
• Consumer billing.• Bill accounting
• Reports for management
MIS FOR UTILITIES
Network connectivity data maintenance for:
• Administrative areas,
• Substations and feeders,
• Distribution transformer centres,
• Consumer master,
• Single-line diagram construction utility,
• Energy accounting,
• Energy input logging,
• Facility to enter or import data for HT consumers,
• Calculation of energy losses at feeder and billing unit level,
• Segregation of technical and non-technical losses,
• Facility to compute consumption for un-metered consumers,
• Energy losses analysis module,
• Energy meters tracking system,
• Interruptions analysis for better maintenance planning,
• Technical architecture, hardware and software platforms,
• Based on client-server architecture, and
• Runs on any open system platform.
HARDWARE CONFIGURATION
Intel P IV, Windows 2000 server
SYSTEM SPECIFICATIONS
Operating system: Windows 2000
RDBMS: Oracle, Sybase
GUI client
STRENGTHS
• Improves the financial performance of the utility.
• Provides a mechanism for reduction in losses.
• Improves efficiency of customer relationship management.
• Improves the level of customer satisfaction.
• Efficient consumer billing and complaint handling system.
• Reduces interruptions to the consumer by better maintenance planning.
• Efficient consumer servicing.
• Provides better administrative control.
SECURITY AND HOUSEKEEPING FEATURES
• Audit reports.
• Defining users.
• Dynamic report engine.
• View and print predefined reports.
• Export output to print file.
• Thematic query facility.
• Basic load flow.
BENEFITS
• Online availability of consumer-related data.
• Flexible billing cycles.
• Fewer consumers billed on average basis.
• Timely billing to consumers.
• Improved revenue and cash flow.
• Process bills of consumers as per reading on the same day.
• Reduces the time required for realization of bills.
• Better receivables management.
• Account for receipts on the same day.
• Enables availability of an online arrears list.
• Enables better strike rate and improvement in collection of arrears.
• Better administrative control of consumer-related business process.
• Tracking of consumer applications.
• Meter-tracking module.
• Inspection report logging facility.
• Security policy enables definition of roles of each employee.
• Data is logged with user ID (identification) and time stamp.
• MIS reports for data authenticity investigations.
• MIS reports for employee-wise meter reading data.
• Better consumer servicing.
• Processing of consumer requests for meter changes, change of name, disconnections, etc.
• Consumer registration module.
• Consumer information module.• Better maintenance planning
• Logging of feeder interruptions with the category
• Maintenance planning based on reason codes
In this context, you may also like to learn about Supervisory Control and Data Acquisition (SCADA).
Supervisory Control and Data Acquisition (SCADA) SCADA involves networking of a group of substations (especially in Metros and large towns) for data collection in respect of all equipment installed at a host station. SCADA systems are developed using a host of enabling core technologies such as those related to Data Communications, Centralized and Distributed Databases, Decision Support, Real-time Computing, Power System Analysis,Geographical Information Processing, Graphics and Multimedia, Distributed Process Control, Simulation and Forecasting and Enterprise Resource Planning (ERP). Some of these Information Systems such as Management Information Systems (MIS) and Maintenance Management Systems (MMS) are generic in structure for all industries, while being specific to a power utility in some functional aspects.
SCADA is an effective tool for remote sensing of system parameters. The distribution system can be monitored on a real time basis and also controlled by issuing commands to remote stations where RTUs are located. The aim of the system is effective load management of the distribution system to improve reliability and efficiency of supply.Since the process is on-line, supply conditions given by the instant loading and voltage profile are effectively monitored, daily and monthly data are readily aggregated, and the energy flow is easily tracked to individual feeders. An immediate benefit is the ability to make instant corrections to network imbalances by way of remote operation of transformer tap-changers, feeder switching, etc., at unmanned substations, thereby optimising workforce deployment and eliminating the monotonous task of manual logging.
Another advantage of SCADA is that voluminous data can be stored and retrieved to generate both active and reactive power load profiles. Such data are available in tabular as well as graphical mode. SCADA also offers electrical parameters with greater accuracy.
The system comprises
– Control Centre equipment,
– Application software,
– Distribution Management Software,
– Communication System,
– RTUs for field data acquisition,
– UPS, etc.
A typical SCADA scheme installed in a typical 33/11 kV is depicted in Fig. where an optical fibre cable has been laid for setting up the data communication channel to interlink their substations with a central control room and set up both point-to-point and point-to-multi-point connectivity. These are:
• optical fibre (OF)
• leased line telephone,
• radio (dedicated) link,
• radio (cellular link), and
•power line carrier (Fig.).
 |
| A Typical SCADA Scheme |
The SCADA system makes efficient use of the bandwidth of the dedicatedcommunication channel by bringing back information from the substation. For example,
•From the substation to the central office/dispatch centre:
− status of circuit breakers (open or closed) and disconnects;
− instrumentation readings (voltages, currents, temperatures, watts, vars, frequency, etc.),
− meter readings (watt hours, var hours, etc.) for billing and for checking, and
− maintenance alarms (ground on DC battery, security/unauthorised entry, low fluid level, high temperature levels, low air pressure, etc.).
•From the central office/dispatch centre to the substation:
−control (open or close) commands to circuit breakers, disconnects, or capacitor banks, and rise/lower commands to change transformer taps.
SCADA is more effective if integrated with load control, Automatic Meter Reading (AMR), emergency load shedding, integrated Var Control, fault location through sectionalisers, trouble call management, and facilities management in a completely automated distribution system. Apart from achieving efficient distribution management, accurate fault analysis and prompt restoration of supply, SCADA makes it possible to identify malfunctioning of equipment in advance for taking corrective action. Historical data for, say, two years can be sorted for future analysis.
•From the substation to the central office/dispatch centre:
− status of circuit breakers (open or closed) and disconnects;
− instrumentation readings (voltages, currents, temperatures, watts, vars, frequency, etc.),
− meter readings (watt hours, var hours, etc.) for billing and for checking, and
− maintenance alarms (ground on DC battery, security/unauthorised entry, low fluid level, high temperature levels, low air pressure, etc.).
•From the central office/dispatch centre to the substation:
−control (open or close) commands to circuit breakers, disconnects, or capacitor banks, and rise/lower commands to change transformer taps.
SCADA is more effective if integrated with load control, Automatic Meter Reading (AMR), emergency load shedding, integrated Var Control, fault location through sectionalisers, trouble call management, and facilities management in a completely automated distribution system. Apart from achieving efficient distribution management, accurate fault analysis and prompt restoration of supply, SCADA makes it possible to identify malfunctioning of equipment in advance for taking corrective action. Historical data for, say, two years can be sorted for future analysis.
 |
| SCADA System at North Delhi Power Limited |
So far we have discussed the IT applications in metering and data acquisition and management. In the next section, you will learn about how IT can be applied in the organisation for MIS and asset management. But before studying further, you should consolidate what you have learnt so far.
I think this article will fully complement you. Please continue publishing helpful topics like this. Regards, from
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