&
Mr. Ankur Jaiswal (Head Infrastructures Solutions)
Enzen Global Solutions Pvt Ltd
Submitted by
Chanmeet Singh Syal
Roll No 1120812207, Batch 2011-13
MBA (POWER MANAGEMENT)
NATIONAL POWER TRAINING INSTITUTE
1

1.1
Introduction
Reeling under an average AT&C (Aggregate Technical & Commercial) losses of around
33%,(over Rs.35000 Crores of cash loss), it is quite impossible for power distribution sector to keep up the desired economic pace without major reforms in the power sector, especially in Distribution. It is an acknowledged fact that the issues involved are complex and no quickfix is possible. Technology will have to play a leading role to shorten the reform gestation period as well as eliminate issue related to "human interference".
Technology innovation can only benefit the sector and system integration has major role to play in empowering the power supply utilities. There is a huge need for specialized, customized and upgraded system solution for the power sector. The Rs 500 billion R-APDRP
(Restructured Accelerated Power Development & Reforms Program) initiative gives high priority for implementation of IT (Information Technology) enabled solutions especially
SCADA/DMS, GIS and distribution automation to reduce AT&C losses.
Supervisory Control And Data Acquisition (SCADA) has been the tool for the utilities to gather the data from remote locations and to analyse the problems and act on it. But it has just been a tool for supervision for Indian utilities, whereas the more advanced distribution utilities has been able to integrate SCADA hardware, Geographic Information System (GIS) and Automation to provide full meaning to SCADA .To integrate the above three on a common platform several software packages and Human Machine Interfaces (HMI) has been used. Software like EMS, DMS, OMS, and GIS has been used to provide supervision and automation to the distribution infrastructure in case of fault or abnormal condition.
2

1.2
Problem statement
Existing distribution systems have certain inherent drawbacks.
• The systems are monitored manually.
• The present system does not ensure reliable and quality power supply.
• The existing billing systems are still unreliable.
• The present system has intensive manpower requirement and over-dependence on experts
• Inaccessible to reach remote locations.
• Trouble-shooting in case of breakdowns is based on the conventional call system through telephone answering machines.
Today, no utility can afford not to have a suitable SCADA system to monitor and control its distribution network. Distribution automation through SCADA systems directly leads to increased reliability of power for the consumers and lower operating costs f or the utility. It results in forecasting accurate demand and supply management; faster restoration of power in case of a breakdown, alternate arrangement for power for important/emergency locations.
Globally, distribution automation by utilities has shown that it pays for itself in a very short span of time.
Hence, finding suitable SCADA software packages for Indian Distribution Utilities is crucial.
1.3
Objective of study :
This report studies various SCADA software packages for Distribution Utilities and their scope of implementation in Indian Distribution Utilities. The report sticks only to the software platforms and not to the hardware part.
We have considered the most promising distribution utilities of the world who has successfully implemented SCADA software for Automation, DMS, and OMS etc.
The report studies the features of most successful SCADA software packages present in the industry and a comparative analysis is done, with the features and properties of
SCADA/DMS specified in the Model Technical Specifications (MTS) document provided by
PFC for implementation through R APDRP PART A.
3

Finally, the report discusses the present scenario of Indian distribution utilities in terms of
SCADA software packages available and recommends the best software platform that can be used in Indian context.
1.4
Scope of Study:
In the report we study the distribution utilities of the technologically developed countries for their SCADA software implemented and the features used.
The study has been kept to some of the most advanced countries and also to countries with similar geographic and grid conditions as Indian distribution companies.
The list of distribution companies included in the study is given in the table 1.1 below:
5
6
2
3
S.
No.
1
4
Software Package Company providing solution iPower for iFix GE
Country/Distribution
Company
New Zealand/PowerNet
Spectrum Power Siemens Austria/ KelagNetzGmbh
Oasys
SCADA,DMS,OMS
Televant(Schneider electric) Rome, Italy/Enel
DMS Ventyx(now ABB) USA/CPS Energy
7
Survalent
LYNX e-terra distribution
Survalent Technologies
Gillam Fei
Alstom
India/Reliance Infra
Georgia US/Flint energy
Geneva/SIG
Metz/UEM
Netherlands /Stedin,
Due to constraint of time we have considered only 12SCADA software packages.
4

2.1 Significance of study:
Significance of the project lies in the fact that it provides an insight into an important aspect of every SCADA system, i.e. the software used within the system. The most obvious software component is the operator interface or Man Machine Interface/Human Machine Interface
(MMI/HMI) package; however, software of some form pervades all levels of a SCADA system. Depending on the size and nature of the SCADA application, software can be a significant cost item when developing, maintaining, and expanding a SCADA system. When software is well defined, designed, written, checked, and tested, a successful SCADA system will likely be produced. Poor performances in any of these project phases will very easily cause a SCADA project to fail.
This report then takes upon applications of SCADA, the exalted aspect, in distribution systems. The applications include control, operation, supervision, measurement and instrumentation, service of SCADA in distribution systems. This is the latest trend in power system protection and control and the future of distribution utilities. Also studies are done to find out the most appropriate SCADA software solution suitable for Indian distribution utilities.
The report compares the software on the basis of the properties (i) reliability, (ii) response,
(iii) business experience, (iv) functionality, (v) graphic user interface, (vi) after sales support and (vii) operating platform and ease of integration with others, and uses the research methodology to evaluate the best SCADA software of the ones considered.
5

2.2 About the Organisation:
Enzen Global Solutions Pvt Ltd is an Upper Quartile Consulting and Services Company working specifically in the Energy and Utilities market. Its corporate goal is to be recognized by organizations operating in this market sector as a company in the top 5 consultancy list in both India and the United Kingdom.

Established in 2006; HQ in Bangalore, India

Focus on Water, Gas and Power

Energy Liberators and Clean Technology Promoters

Advisors and Knowledge Practitioners

6 Indian Offices and 4 International Offices

2,000+ Knowledge Practitioners

Enzen is ISO 9001:2008, ISO 14001:2004, ISO 27001 and OHSAS 18001:2007 accredited; ‘VERIFY’ certified
Enzen, as a leading consulting organization is focused on bringing intellectually engendered market leading solutions to meet the business challenges of its customers in the Energy and
Utilities market. It offers a variety of customer engagement models which include fixed price, risk and reward, profit sharing based on increased operational efficiency or quite simply fixed man day consulting rates.
Specialties
Consulting, strategy formulation and design, development and implementation services, process optimization, energy efficiency, energy demand management
Enzen Global is an innovative, knowledge-based energy and utility enterprise serving the
Gas, Power and Water sectors.
It provides outcome based turnkey solutions, blending industry best practices and leading edge ideas with a continuous focus on meeting the customers’ expectations.
Enzen is also a PFC empanelled company to provide Meter Data Acquisition and GIS solutions under the R-APDRP program. It is working with over 100 major Energy and Utility
6

enterprises across the UK, India, Europe and the Middle East in regulated as well as deregulated markets. With a clientele of over 100 utilities and industries spread across ten nations, its experienced knowledge practitioners have worked closely with many of Fortune
500 companies. With 1,500 plus knowledge professionals, and still growing, Enzen is a young organization with a rich repertoire of experiences
Power Practices:
 India’s largest power distribution franchisee operator (250,000+ Consumers)

Key Indian Power Utility Customers include MPPVVNL, NESCO, WESCO,
SOUTHCO, CESU, DHBVNL, CSEB, BESCOM, HESCOM, KSEB

Key International Power Utility Customers include National Grid, EoN, EdF, UK
Power Networks, Drax Power, Western Power Alliance

Proprietary Solutions for India utility markets (Distribution and Generation) and for
MDAS

Working with KSEB in modernization of base Power Infra

AMR solutions for BESCOM

SaaS based Asset Management Solutions

Pioneer in Energy Efficiency drive through Discom (AgDSM)
7

2.3 Need of SCADA in Indian Power Sector:
The efficient and reliable power supply to the consumer is the primary function of any distribution system. So, in distribution systems certain measures are taken for supervision, control, operation, measurement and protection. These are highly tedious works that take lot of manpower. So, the need of advanced automatic control systems to reach the required destination is becoming mandatory, to improve the present distribution system.
The Indian power sector is in the midst of a transformation process from being Energy suppliers to becoming Energy Service Companies. The Distribution Utilities face new challenges every day and have to improve profits by reducing operating and maintenance costs, while providing customers with a reliable power supply and a broad range of services.
The demand-supply gap in power in India is expected to grow by at least ten per cent this year. The trend is expected to continue in the near future with no significant generating capacity coming up in the country due to fuel (coal & natural gas) shortages and this may cause power crisis.
It is imperative that power utilities need to look at increasing efficiencies in distribution networks, which are among the highest transmission and distribution losses in the world close to around 30 per cent. In addition, the social pricing for rural and other sectors, increases pressure on utilities to improve productivity by reducing operating and maintenance costs to remain financially viable.
To achieve rapid success, the effective use of Information Technology is essential. With IT courting telecom, the new millennium has leap frogged into a revolution in networking and communication technologies to offer automation as a solution to improve distribution efficiencies. The most advanced automatic control system, which can perform the operations like monitoring and control, is SCADA. SCADA is the application of computer in power systems. Distribution automation is the major up gradation of any distribution system. This can be achieved by implementing SCADA in distribution systems.
Distribution Management System is a tool for enterprise-wide management of an electric utility system for efficient operations, which enhances operational outputs and translates it into economic benefits. Some of the initiatives in distribution management include complete distribution automation, City power distribution automation, and SCADA based power
Distribution Automation Systems
8

Existing distribution systems have certain inherent inefficiencies due to their legacy. For one, most systems are monitored manually. This results in maintenance taking place only during breakdowns. The present system also does not ensure reliable and complete power system and usage information that can facilitate trend forecasting or help the utility in better analysis and planning.
At places, the billing systems are still unreliable. While the present system has intensive manpower requirement and over-dependence on experts, it is still a logistic nightmare to reach remote locations. Even trouble-shooting in case of breakdowns is based on the conventional call system through telephone answering machines.
Internationally, power generation and power transmission and distribution attract equal investments. In India too, in the last couple of years, utilities have started investing increasingly in various distribution automation tools for both cost reduction and service benefits.
One major tool available for power utilities is the Supervisory Control And Data Acquisition
(SCADA) system. SCADA refers to a system that enables an electric utility to remotely monitor, coordinate, control and operate distribution components, equipment and devices in a real-time mode from remote locations with acquisition of data for analysis, and planning from one central location.
Today, no utility can afford not to have a suitable SCADA system to monitor and control its distribution network. Distribution automation through SCADA systems directly leads to increased reliability of power for the consumers and lower operating costs f or the utility. It results in forecasting accurate demand and supply management; faster restoration of power in case of a downturn and a quick, alternate arrangement for power for important/emergency locations.
The utilities are in a better position to undertake both active and reactive power management and with better anticipation of trouble and greater trouble-shooting through remote access.
Predictive maintenance results in reduced cost of maintenance of power system devices, thereby extending their life.
Distribution automation through SCADA also reduces human influence and errors. It offers complete power system controls and data acquisitions in a central location, thereby assisting operators in faster decision-making for healthy power supply. It also ensures reliability and
9

quality of power supply (minimum fluctuation in voltage supplies) for the consumers.
Automated meter reading for bulk consumers, who contribute major revenues, can check loss due to possible meter tampering.
10

3.1
Review of Literature
A G Bruce et al[2004] says the potential for the SCADA system to directly contribute to load curtailment. This paper presents an analysis of SCADA system reliability in terms of its expected aggregate contribution to load curtailment on the power system. Expressing this aggregate in system minutes and applying an appropriate damage cost function then provides an annual cost measure of SCADA system reliability worth. A composite generation and transmission system reliability evaluation technique is used to perform the numerical analysis of the joint SCADA and Power system model. This performs a Monte-Carlo simulation and includes an optimal power flow for enumerating gnd load curtailment states and analysis of
SCADA system component connectivity to determine availability of SCADA control. The application of this analysis is illustrated in a comparison of two alter native SCADA architectures. Trans Power has adopted a sub transmission SCADA architecture which utilises terminals operating off its national SCADA system. These terminals have replaced separate systems located in each area. The objective of the evaluation being to quantify the increased exposure to financial losses due to joint load curtailment.
Analysis of Power System reliability provides a means of determining when power system failures or load curtailment’s occur. SCADA failures are assumed to occur independently of load curtailment’s and occur when a power system
Operator is unable to retrieve data from or issue controls to primary plant associated with one or more busses. In each case the controls or retrieved data is a necessary part of load restoration. Determining whether a bus is controlled or uncontrolled is done by analysing, the availability of control paths through the
SCADA system. This system is a detailed I model representing the master station, SCADA data communications network, remote terminal units and the data wide area network (WAN).
Charles W. Newton- Mahmood Makhdoomi, et al[2005] says that now a days T&D
Automation Systems is one of the most important subjects in this fields . A survey about
SCADA, EMS and DMS in electrical utilities in several Countries are gathered and classified in following four Regions: Eastern Europe, Latin America, Mid East /Mediterranean/
Africa, Asia Pacific. In this paper the trend of development of SCADA , EMS, DMS , OMS,
RTUs ,PLCs as well as theirs required OS , CPU platforms and protocols in the sample countries are investigated . The obtaining results from the above mentioned survey will lead the power network operators to select the best system for their own networks.
11

In this paper the trend of development of SCADA, EMS, DMS, OMS, RTUs, PLCs as well as their required operating systems, CPU platforms and protocols in the sample countries are investigated.
It is shown that the total interest in T&D automation are growing dramatically and there is a good market for these software and hardware systems in coming years. While HP is and will be the dominant CPU platform around the world, Microsoft Windows gradually is becoming the most selected operating system everywhere in these systems, i.e. servers, workstations and clients although there will be a close competition between SUN and Windows for server applications.
A.Ilo, Siemens, et al [Turin, 6-9 June 2005] says in the new conditions of the fast growth of decentralized generation, electric market liberalisation, and of the last numerous blackouts it is expected a dramatic change in the management and operation of the electricity grids worldwide. In distribution level the historic passive distribution network operation will vanish and a new active distribution network operation will be indispensable. On these terms beside other steps the implementation of a SCADA/DMS system and the maintenance of the relevant data is required too. In the present work the implementation impact of the
Distribution Management System on the technical and economical performance of the distribution networks is investigated. Results show that even the expensive implementation of the SCADA/DMS, which provides state-of the- art operational and technical support, the investments will be paid back in the first exploitation years.
IEEE, Distribution Automation Working group , et al[dec,2007] says this White Paper,
“Smart Grid for Distribution Systems” addresses the benefits and challenges of implementing the many different Distribution Automation functions. Distribution systems have traditionally not involved much automation. Distribution equipment, once installed on feeders, was expected to function autonomously with only occasional manual setting changes. Capacitor bank switches might switch on or off based on local signals, such as time of day or current.
After a local fault condition, reclosers would attempt reclosing a set number of times before locking out. Lateral fuses would blow if the current became too high. Recently, in response to the growing demand to improve reliability and efficiency of the power system, more automation is being implemented on the distribution system.
Many technical issues affect the cost-benefit analysis of implementing different types of distribution automation functions. However, some of the technologies for meeting those
12

requirements have universal themes that present the key challenges to implementing automation. The development of Distribution Automation Scenarios, based on both secondary and primary DA functions, allows utilities to understand both the benefits and the challenges involved in implementing these functions. Primary functions typically require heavy capital expenditures to implement equipment, communication, and data infrastructures whose payback can only truly come when one or more secondary functions utilize these infrastructures. Therefore, using the Use Case Scenario approach permits utilities to fully appreciate the need for a comprehensive, multi-function approach to distribution automation.
The cost and other challenges of implementing the primary functions may be daunting.
However, often a phased approach can be used in distribution automation, because, unlike tightly networked transmission systems, distribution systems can fairly easily deploy pilot projects or initial implementation of DA functions that affect only a few feeders. Lessons can be learned from these initial deployments which can improve eventual deployment of the functions to a larger set of feeders.
Dr. Graham Ault et al[June 2005] says that Advanced Distribution Automation (ADA), takes existing network automation further, Main focus is on system reliability, Addresses key utility drivers in the US and UK i.e. (i) Distribution reliability, (ii) Capital and operating cost control, (iii) Customer focused operation& (iv) Connection of distributed and renewable generation. ADA provides Primary and secondary system solutions.
Conclusion of study provides that (i) Strong parallels between distribution automation and active network management exist, (ii) Substantial programmes of research, development and demonstration for active network management are underway,(iii) Active network management offers the prospect for more economic integration of renewable into power systems & (iv) Integrated network automation and generation management possible in future.
Hari Kumar Naidu et al [2010] evaluates the advances in telecommunication, Information
Technology and networking which offer SCADA (Supervisory Control and Data Acquisition)
Power supply Distribution automation as a solution to improve power distribution efficiencies.
This paper also discusses the result of the indigenously developed prototype hardware and software model utilising the latest embedded technology innovation for SCADA Power
13

Distribution Automation Systems for reliable performance of power system. This is vividly evident that SCADA Power Distribution Automation Systems offer as a solution to improve power distribution efficiencies. Also the indigenously developed sample prototype hardware and software model utilising the latest embedded technology innovation for SCADA Power
Distribution Automation Systems will reliably perform the power system.
Gautam Agrarwal et al[2010] says Electric power utilities worldwide are increasingly adopting the computer aided monitoring, control and management of electric power distribution system to provide better services to electric consumers. The demand of reduced outage rates (both quality and duration) has led most electric companies to reconfigure their distribution networks from radial to normally opened looped, so once faulted section is isolated , power can be restored to the rest of the network from an alternative sources. This task is economically achieved by introducing distribution automation switches which are remotely controlled from a central control room. In this manner, quality and continuity of service to the customer are vastly improved as is user convenience. Therefore, the focus of electric research and development activities worldwide is to automate the electric power distribution system utilizing recent advancement in the area of Information Technology and data communication system.
SCADA plays an important role in power system supervision and remote control systems.
SCADA and IED go hand in hand for greatly enhancing substation automation and reducing human intervention. Power system automation using IED according to IEC61850 and interoperability between relays provides the future trends enclosing in to intelligent and smart grids. On the other hand, the main motivation for accepting the distribution automation in developing countries such as India is to improve operating efficiency of distribution system.
This indicates worldwide interest for distribution automation at present. Looking at the interest of power utilities for distribution automation, academic institutions are now taking interest to introduce courses and R & D activities in the field of distribution automation in the regular academic curriculum. The US Stimulus Bill has allocated tens of billions to Smart
Grid and Renewable Energy Development. The Indian Government too, recognizing the potential of the Distribution Automation technology is creating a Panel of vendors for the implementation of SCADA/DMS.
14

M. Sadeghi et al [2011] says that a Novel Distribution Automation is the bonnie state of art,
Comprising the new architecture based on the flexible electrical network of component together with an open communication structure debate the Future Distribution Automation
System. IUT (Intelligent Universal Transformer) comprises from power electronic base equipment in addition with traditional current transformer introducing as an IED (Intelligent
Equipment Devices) for ADA (Advanced Distribution Automation) in forthcoming days. In contrast to ordinary transformer, IUT has full control compatibility as it has been considered for intelligent device. In this regards FLC (Fuzzy Logic Control) is an advanced method based on fuzzy logic concept (first issued by Lotfy Zadeh) emphasizes on fuzzy algorithms which are formulated by linguistically rules, employing expert knowledge. Model free system, nonlinearity, robustness and flexibility under parameter variations are the benefit advantages resulting from the fuzzy logic controllers. In this approach four layers IUT topology with the diverse services like DC (Direct Current) voltage option, 400 HZ utility for communication, 120 and 240 V AC (Alternating Current) 60 HZ together with fuzzy logic controller have been considered for evolving the stability, reducing the uncertainty and enhancing the efficiency of whole system. They further conclude that FLC control methodology is concerned for overcoming on ambiguous conditions, nonlinear and complex system, enhancing the robustness for the new modern technology described as IUT.DC and three phase output voltages are the benefits arises by using four layers IUT topology. In this simulation four FLC controllers take the role of control and guarantee the stability and keep out the whole system from disturbances in input output stages. It also leads to efficiency enhancement in system performances. ADA infrastructure has been raised in terms of future necessity will comprise the next distribution automation. It is directed towards full network functionality. Reliability enhancement is a part of innovation could be stated using modern adaptive solution for forthcoming projects especially for IUT in smart grid of future.
Bob Uluski, Electric Power Research Institute. et al[July 20, 2011] says Proposed DMS project must have (i) Address significant business problem(s), (ii) Support important business driver(s), (iii)Provide monetary payback within an acceptable period to offset the expenditure. Technology for technology’s sake is not an acceptable reason to proceed with a significant automation project. At best, will result in demonstration (“pilot”) project with little support that goes nowhere.
15

The implementation strategy should be divided into the following key activities as
Procurement, Design and Test, Installation, Implementation and Commissioning,
Sustainment.
Chuck Newton, Newton-Evans Research Company ,et al [September, 2011] says in his research that The 2010 survey data support the viewpoint that spending for mature or traditional control center technologies such as EMS and SCADA systems had decreased a bit over the 2008- 2009 years but is now holding “steady” and in fact starting to show positive growth dependent upon the world region being discussed, and whether proposed new contracts were signed yet in 2010 or will be held off until 2011 or 2012. Real growth for this related group of computer-based control and monitoring systems derives from increased spending on expanded distribution systems and on a new generation of intelligent electronic devices for use in the distribution network, smarter transmission equipment and a new generation of software applications.
This new study corroborates similar findings reported in the comparable 2001, 2003,
2005 and 2008 studies. One major change is that the values of “turnkey” systems procurements remains down somewhat around the world, as more and more utilities opt for system replacements and upgrades without rework of the entire supporting infrastructure
( control center construction, telecomms, et al ).
Nonetheless, we do see continued expansion (and automation) of transmission and distribution networks in the developing nations, especially in the GCC states, Brazil, China and India. On a global basis, Newton-Evans estimates that about $445 million (range of $384 million to $500 million) will be spent during the current year of the three year forecast period for EMS systems, software licenses for EMS applications, field and control center hardware to support EMS systems, and related engineering, training, and maintenance and support services. Over the three-year forecast period (2010-2012), low estimates of about 1.3 billion dollars will likely be spent for EMS systems and related software and services. If all forecasted procurements are made during this same three-year period, then contracts worth about 1.7 billion dollars are likely to be awarded. Some countries are planning large re investments in EMS during this period, but over the years, it has been Newton-Evans’ experience that project funding is often delayed by 12-18 months from original plans.
16

3.2 Research Methodology:
This project of is based on the basic concept of research methodology. The following concepts are directly or indirectly used while doing this project.
Research Design
This study is an exploratory research to study the features of the SCADA Software for distribution utilities and to find the SCADA Software most suitable for Indian scenario.
Universe and Survey Population
The universe in this case is the available SCADA/DMS software available in the world market and Model Technical Specifications (MTS) document provided by PFC for IT implementation in distribution utilities through R APDRP PART A. Due to limited time it was difficult to cover the entire universe.
Sample
The sample consists of all the distribution utilities which have successfully implemented
SCADA/DMS/OMS software and automation.
Collection of Data
Various companies providing SCADA solutions and their websites, Successful distribution utilities, companies empanelled with PFC, articles, journals etc are the sources of data for this study.
Analysis Pattern
Data analysis is done by comparative study of software packages on the basis of following:
Reliabi lity
Response Business
Experience
Functionality Graphic user
After sales
Operating platforms
Interface support and ease of integration
Very High
High
Average
Low
Very Low
17

4.1 Introduction to SCADA:
These days sophisticated working environment has become a need of the hour. Analysis of the following problem would make the need more specific. For example: Consider that circuit breaker near a very important locality has tripped and the supply has been cut-off. The power supply has to be restored as early as possible so that the consumers do not get agitated.
Hence the question of centralized monitoring and control arises. If the person back in control room knows the position of circuit breakers and could control it from there itself, the power is restored quickly and hence power disruption is avoided. To achieve this control data is to be acquired precisely and accurately. Thus the above problem shows us that there is need of centralized control and monitoring system, which in this age is achieved by using the
SCADA system.
SCADA’s powerful tools are being increasingly used for centralized control of remote processes to optimize operation of really complex systems such as automation of energy distribution systems, generation of electricity, customer information system and engineering analysis.
SCADA is an acronym for Supervisory Control And Data Acquisition. As the name indicates, it is not a full control system, but rather focuses on the supervisory level. As such, it is a purely software package that is positioned on top of hardware to which it is interfaced, in general via Programmable Logic Controllers (PLCs), or other commercial hardware modules.
SCADA systems used to run on DOS, VMS and UNIX; in recent years all SCADA vendors have moved to Microsoft NT and some also to Linux.
18

4.2 SCADA System Components
A typical SCADA system broadly comprises the following components a) At field (substation) level, the SCADA comprises Feeder Remote Terminal Units
(FRTUs), Remote Terminal Units (RTUs), Fault Passage Indicators (FPI), Input / Output racks, transducers and auxiliary relay panels. b) System level components: These are located at the Control centre level and comprise of
Front End Processors (FEPs), Database servers, Man Machine Interface, Video projection system. Critical system level components, mainly Front End Processors and Database servers shall have redundancy. There shall also be multiple MMIs with provision to view the entire network from each of them. c) Communication media: This comprises the media for communication between field and system level components and could be Fibre optic, leased lines, private microwave networks,
LAN/WAN and wireless technologies such as GSM,GPRS,CDMA etc and the associated end terminal equipment. The communication media shall also have redundancy.
4.2.1 Hardware Architecture
One distinguishes two basic layers in a SCADA system: the "client layer" which caters for the man machine interaction and the "data server layer" which handles most of the process data control activities. The data servers communicate with devices in the field through process controllers. Process controllers, e.g. PLCs, are connected to the data servers either directly or via networks or field buses that are proprietary, or non-proprietary. Data servers are connected to each other and to client stations via an Ethernet LAN. The data servers and client stations are NT platforms but for many products the client stations may also be W95 machines.
19

Figure 1. shows typical SCADA hardware architecture.
4.2.2 Software Architecture
The products are multi-tasking and are based upon a real-time database (RTDB) located in one or more servers. Servers are responsible for data acquisition and handling (e.g. polling controllers, alarm checking, calculations, logging and archiving) on a set of parameters, typically those they are connected. However, it is possible to have dedicated servers for particular tasks, e.g. historian, data logger, alarm handler.
20

Figure 2. shows a SCADA architecture that is generic for the products that were evaluated.
4.23. Communications
Internal Communication
Server-client and server-server communication is in general on a publish-subscribe and event-driven basis and uses a TCP/IP protocol, i.e., a client application subscribes to a parameter which is owned by a particular server application and only changes to that parameter are then communicated to the client application.
Access to Devices
The data servers poll the controllers at a user defined polling rate. The polling rate may be different for different parameters. The controllers pass the requested parameters to the data servers. Time stamping of the process parameters is typically performed in the controllers and this time-stamp is taken over by the data server. If the controller and communication protocol used support unsolicited data transfer then the products will support this too.
The products provide communication drivers for most of the common PLCs and widely used field-buses, e.g., Modbus. Of the three field buses that are recommended at CERN, both
21

Profibus and World fip are supported but CAN bus often not. Some of the drivers are based on third party products (e.g., Applicom cards) and therefore have additional cost associated with them. VME on the other hand is generally not supported.
A single data server can support multiple communications protocols: it can generally support as many such protocols as it has slots for interface cards.
The effort required to develop new drivers is typically in the range of 2-6 weeks depending on the complexity and similarity with existing drivers, and a driver development toolkit is provided for this.
4.2.4 Functionality
Access Control
Users are allocated to groups, which have defined read/write access privileges to the process parameters in the system and often also to specific product functionality.
HMI/MMI
The products support multiple screens, which can contain combinations of synoptic diagrams and text.
They also support the concept of a "generic" graphical object with links to process variables.
These objects can be "dragged and dropped" from a library and included into a synoptic diagram.
Most of the SCADA products that were evaluated decompose the process in "atomic" parameters (e.g. a power supply current, its maximum value, its on/off status, etc.) to which a
Tag-name is associated. The Tag-names used to link graphical objects to devices can be edited as required. The products include a library of standard graphical symbols, many of which would however not be applicable to the type of applications encountered in the experimental physics community.
Standard windows editing facilities are provided: zooming, re-sizing, scrolling... On-line configuration and customisation of the MMI is possible for users with the appropriate privileges. Links can be created between display pages to navigate from one view to another.
22

Alarm Handling
Alarm handling is based on limit and status checking and performed in the data servers. More complicated expressions (using arithmetic or logical expressions) can be developed by creating derived parameters on which status or limit checking is then performed. The alarms are logically handled centrally, i.e., the information only exists in one place and all users see the same status (e.g., the acknowledgement), and multiple alarm priority levels (in general many more than 3 such levels) are supported.
It is generally possible to group alarms and to handle these as an entity (typically filtering on group or acknowledgement of all alarms in a group). Furthermore, it is possible to suppress alarms either individually or as a complete group. The filtering of alarms seen on the alarm page or when viewing the alarm log is also possible at least on priority, time and group.
However, relationships between alarms cannot generally be defined in a straightforward manner. E-mails can be generated or predefined actions automatically executed in response to alarm conditions.
Logging/Archiving
The terms logging and archiving are often used to describe the same facility. However, logging can be thought of as medium-term storage of data on disk, whereas archiving is longterm storage of data either on disk or on another permanent storage medium. Logging is typically performed on a cyclic basis, i.e., once a certain file size, time period or number of points is reached the data is overwritten. Logging of data can be performed at a set frequency, or only initiated if the value changes or when a specific predefined event occurs. Logged data can be transferred to an archive once the log is full. The logged data is time-stamped and can be filtered when viewed by a user. The logging of user actions is in general performed together with either a user ID or station ID. There is often also a VCR facility to play back archived data.
Report Generation
One can produce reports using SQL type queries to the archive, RTDB or logs. Although it is sometimes possible to embed EXCEL charts in the report, a "cut and paste" capability is in
23

general not provided. Facilities exist to be able to automatically generate, print and archive reports.
Automation
The majority of the products allow actions to be automatically triggered by events. A scripting language provided by the SCADA products allows these actions to be defined. In general, one can load a particular display, send an Email, run a user defined application or script and write to the RTDB.
The concept of recipes is supported, whereby a particular system configuration can be saved to a file and then re-loaded at a later date.
Sequencing is also supported whereby, as the name indicates, it is possible to execute a more complex sequence of actions on one or more devices. Sequences may also react to external events.
Some of the products do support an expert system but none has the concept of a Finite State
Machine (FSM).
4.2.5 Application Development
Configuration
The development of the applications is typically done in two stages. First the process parameters and associated information (e.g. relating to alarm conditions) are defined through some sort of parameter definition template and then the graphics, including trending and alarm displays are developed, and linked where appropriate to the process parameters. The products also provide an ASCII Export/Import facility for the configuration data (parameter definitions), which enables large numbers of parameters to be configured in a more efficient manner using an external editor such as Excel and then importing the data into the configuration database.
However, many of the PC tools now have a Windows Explorer type development studio. The developer then works with a number of folders, which each contains a different aspect of the configuration, including the graphics.
Development Tools
24

The following development tools are provided as standard: a graphics editor, with standard drawing facilities including freehand, lines, squares circles, etc. It is possible to import pictures in many formats as well as using predefined symbols including e.g. trending charts, etc. A library of generic symbols is provided that can be linked dynamically to variables and animated as they change. It is also possible to create links between views so as to ease navigation at run-time. a data base configuration tool (usually through parameter templates). It is in general possible to export data in ASCII files so as to be edited through an ASCII editor or Excel. a scripting language an Application Program Interface (API) supporting C, C++, VB a Driver Development Toolkit to develop drivers for hardware that is not supported by the
SCADA product.
4.2.6 Evolution
SCADA vendors release one major version and one to two additional minor versions once per year. These products evolve thus very rapidly so as to take advantage of new market opportunities, to meet new requirements of their customers and to take advantage of new technologies.
As was already mentioned, most of the SCADA products that were evaluated decompose the process in "atomic" parameters to which a Tag-name is associated. This is impractical in the case of very large processes when very large sets of Tags need to be configured. As the industrial applications are increasing in size, new SCADA versions are now being designed to handle devices and even entire systems as full entities (classes) that encapsulate all their specific attributes and functionality. In addition, they will also support multi-team development.
As far as new technologies are concerned, the SCADA products are now adopting:
Web technology, ActiveX, Java, etc.
25

OPC as a means for communicating internally between the client and server modules. It should thus be possible to connect OPC compliant third party modules to that SCADA product.
FUNCTIONAL SOFTWARE MODULE OF SCADA
Integrated Hardware/Software Platform
SCADA System
Power Analysis Software: Network Topology, State Estimation, Dispatch Power Flow,
Network Equivalence,
Short-circuit Current Calculation, Voltage Control/Reactive Power Optimization, Static
Security Assessment,
Load Forecasting and so on
Dispatch Information Management System (DMIS)
Dispatcher Training Simulation System (DTS)
Tele-Meter Reading System(TMR)
43 WHY SCADA?
Visibility for the network operation.
Real-time, accurate and consistent information of the system.
Flexibility of operational controls.
Faster fault identification, Isolation & system restoration.
Extensive reporting & statistical data archiving.
Central database and history of all system parameters.
Improve availability of system, Optimized Load Shedding.
26

SCADA in distribution system & utilities is used for Distribution Automation, DMS, OMS i.e. Distribution Management System and Outage Management respectively. These has been implemented by a lot of distribution utilities across the world the achieve better monitoring and control and to improve power quality, reliability & customer satisfaction.
The goal of Advanced Distribution Automation is real-time adjustment to changing loads, generation, and failure conditions of the distribution system, usually without operator intervention.
Presently the distribution utilities across the world are either implementing or have implemented distribution automation solutions for fulfilling one or more of these business objectives:
Better monitoring & control of their distribution assets
To reduce their Aggregate Technical and Commercial (AT&C) losses
As part of their Smart Grid compliance put by the regulation
SCADA systems are globally accepted as a means of real-time monitoring and control of electric power systems, particularly for generation, transmission and distribution systems.
RTUs (Remote Terminal Units) are used to collect analog and status telemetry data from field devices, as well as communicate control commands to the field devices. Installed at a centralized location, such as the utility control center, are front-end data acquisition equipment, SCADA software, operator GUI (graphical user interface), engineering applications that act on the data, historian software, and other components.
Recent trends in SCADA include providing increased situational awareness through improved GUIs and presentation of data and information; intelligent alarm processing; the utilization of thin clients and web-based clients; improved integration with other engineering and business systems; and enhanced security features.
27

4.4 What is SCADA/EMS and SCADA/DMS
SCADA/EMS (Supervisory Control and Data Acquisition/Energy Management System) supervises controls, optimizes and manages generation and transmission systems.
SCADA/DMS (Distribution Management System) performs the same functions for power distribution networks.
Both systems enable utilities to collect, store and analyze data from hundreds of thousands of data points in national or regional networks, perform network modeling, simulate power operation, pinpoint faults, preempt outages, and participate in energy trading market.
SCADA/EMS
SCADA/EMS systems are a complete solution which realizes the functions of electric power system supervisory & control and data acquisition, electric power network safety & economical operation and analysis, real-time dispatch management, dispatcher training, data communication between different centers, etc.
SCADA/ DMS
DMS application assists the distribution operator managing the distribution system operations effectively. DMS is typically associated with receiving real-time status and analog inputs from the distribution system, and the generation of supervisory control commands to various control devices such as distribution breakers, switches and reclosers, switched capacitor banks, voltage regulators, ring main units (RMU's) and on load tap changers (OLTCs) etc.
The importance of DMS will increase as additional amounts of customer generation, energy storage, and demand response are placed on distribution systems. DMS is receiving a lot of attention because it can provide solutions to many challenges distribution organizations face today.
28

Figure 3 below contains a listing of DMS applications, functionality and benefits:
29

Figure 4 : SCADA packages utilized at various levels of power sector
30

Figure 5 DMS integration with various interfaces
Figure 6 Integration of the software GUI in SCADA application
31

Challenges in the DMS Implementation :
The key issues and challenges faced by the Distribution Utilities are listed below:
Insufficient Data & it's Quality
Isolated Utilities IT/OT/ET applications
Communication Infrastructure
Modernization of the existing switchgear
Change of existing business process
Enterprise wide uniform naming convention
32

5.1.
Name of SCADA software iPower with iFIX
Name of company
GE iFix has amazing Power & Distribution applications, for instance:
Drivers: more than 200+ drivers (DNP3, IEC61850, OPC, Modbus/RTU/ASCII/TCP, Enron
Modbus, etc.)
Apps: There are specialized Power & Distribution iFix versions known iPower
Historical: Proficy Historian is capable to retrieve data at 100ms and store offline data at 1ms with Timestamp (commonly found in remote terminal units in distribution apps). iFIX offers a robust SCADA engine, rich set of connectivity options, open architecture and highly scalable and distributed networking model. Used in a variety of applications across diverse industries, it is ideally suited for applications as simple as typical HMI applications such as manual data entry and validation to very complex SCADA applications like batching, filtration and distributed alarm management. It also complies with industry standards-making it ideal as part of more IT-focused real time data management system. Providing a window into your total operations cycle, iFIX enables faster, better intelligent control and visibility into your operations.

 iFIX is a proven scalable solution, which can operate on a single node or scale up to
200+ nodes
Although iFIX has the ability to connect to most any device via an OPC server. iFIX's also comes with many standard built in native drivers addressing the need for connecting the major PLC brands
 iFIX is completely hardware independent and provides the flexibility of

 communicating with multiple makes of hardware from a single server.
The wide variety of prebuilt dynamos, the user-friendly interface of the development
'Workshop' environment and the integration with the rest of the Proficy suite enables you to deploy solutions faster than the competition
VBA Scripting and .NET component hosting enables easy connections to IT level systems and VBA/.NET are the world’s most used computer languages for industry.
33

 Out of the box, you get the best in class, full-featured SCADA system along with enhanced failover and Historian integration that is simple to develop and easy to maintain
 Upgrading from previous iFIX versions is easy & seamless
 The e-signature functionality is the best in the business
Typical application solutions include:

Substation Management Solutions

Rural & municipal utility SCADA Solutions

In Plant Distribution Solutions
Core SCADA Capabilities
• Real-time data communication, database management, real-time dynamic data display
• Secure operator supervisory control
• Alarm, event, sequence of events, momentary change detection
• Historical collection with real-time and historical graphing
• Standard SCADA Historian or full Enterprise-wide Historian options
• User-based security
• Online configuration
Safety Features
• Select before operate control
• Control timeout; control fail alarm
• Simultaneous control lockout
• Control tagging (control lockout)
• Information tagging
Standards and Tools
• Microsoft VBA for scripting, customization and automation
• ActiveX
• OPC
• SQL
• ODBC
• COM
34

• DCOM
• TCP/IP
• Multi Speak
Connectivity
• Proven communications software for hundreds of brands of RTUs, IEDs, PLCs and other
I/O devices
• Industry standard communications protocol compatibility for DNP 3.0, IEC 870-5-101,
870-5-104, ICCP and IEC 61850
• Full OPC server and client support
• Multiple simultaneous serial and/or Ethernet communications channels
• PI and Proficy Historian connectors
• ODBC and SQL tools
• VisiconX® SQL wizard
• Multi Speak compliant
Display and Graphics
•
Multiple monitors per workstation
•
Windows-familiar navigation including Back, Forward, Home, Favorites
•
Object-oriented graphics
•
Industry specific object libraries
•
Pan, zoom with automatic declutter
•
Bus colouring and portable ground display
•
Configurable multi-pen charts with left/right scroll, X-Y, and configurable look and feel
Standard Lists/Reports
• Alarms
• Events
• Sequence of events
• Off-Normal
• Dynamic database display
• Control tag
• Information tag
• Manual overwrite
• Off-Scan
• Operator notes
35

Requirements
• Proficy HMI/SCADA iFIX
• Microsoft® Windows 2003 Server,Windows XP or later
• Pentium IV; 512MB RAM or better
• 120MB disk space; CD ROM
• TCP/IP LAN interface
• SVGA or higher
• Pointing device
Case Study:
Location
Customers
Total I/O
Servers
Clients
PowerNet in Invercargill, New Zealand
64,000
10,000
Dual Servers in redundant automatic fail-over configuration
 Two control room Operator workstations, each with three monitors working as a single desktop
 Three clients distributed on the corporate LAN
LAN
Software
Dual redundant LAN, LAN switch interface to corporate LAN
Windows 2003 Server; iFIX 3.5; iPower 2.40
Additional
Applications
Catapult OnDemand - automated load management
Custom Developments Developed by Catapult Software:


OPC driver to Plessey SCADA FECP
OPC driver to Landis &Gyr Ripple Plant Controllers
Communications &
Remotes



Protocols : DNP-3.0; Plessey FECP; Landis &Gyr
Media : UHF radio, copper wire (mixture of 300 & 1200 baud)
Remotes : Harris D20 (Via DNP); Schweitzer Relays (via
DNP); Kingfisher RTU (via DNP); NuLec Reclosers (via
DNP); L&G Load Controllers; Plessey Dataterm RTU
36

On Demand Power Distribution
PowerNet Limited, based in Invercargill, New Zealand, is a joint venture company that manages the electricity reticulation networks of The Power Company Limited, Electricity
Invercargill Limited, and OtagoNet Joint Venture. Established on July 1, 1994, the company’s core business is to manage electricity network assets in a cost-effective way. This strong commercial focus means PowerNet is able to achieve efficiencies in a monopolycontrolled industry. PowerNet is responsible for the distribution of electricity to 64,000 rural, residential and industrial customers. The company adheres to a vision and value code to serve its customers through understanding their needs and expectations and responding accordingly. One of the ways they do that is make the most of the technology available to them. This allows them to reward their stakeholders – customers, employees, suppliers, and owners – by producing a sound financial performance and contributing to the wellbeing of the community and the environment.
PowerNet turned iPower, a product specifically for electric utility SCADA operations based on GE Fanuc’s Proficy™ HMI/SCADA iFIX, a robust HMI/SCADA solution that provides process visualization, data acquisition and supervisory control of operations. iPower delivers a modern, sophisticated and “evergreen” SCADA software to electric utilities that includes all of the safety, performance, reliability and management needs to efficiently operate a electric network.
GE added the software services needed to meet the requirements of electric distribution
SCADA. The result was a sophisticated Windows®-based SCADA system, affordable and perfect for the needs of rural electric cooperatives. When PowerNet began its upgrade project they looked at UNIX based SCADA systems and decided that they were expensive to install and maintain. Microsoft®Windows-based systems developed specifically for electric utilities are sold in relatively small numbers and therefore do not have the richness provided by the
ProficyiFIX platform.
Data Management: A Competitive Edge
A key difference between GE Fanuc’s Proficy iFIX and other Windows-based SCADA products is that iFIX offers data management capabilities that enable users to easily extract information from SQL Server 7, Oracle 7.x, Sybase, Informix, Access and other databases.
The single largest cost when installing a new SCADA system is the time it takes to configure the system. Less obvious at purchase time is the cost of maintaining the integrity of the data, plus ongoing expansion of the system over the years of ownership.
37

iPower tools make configuring and maintaining an electric utility SCADA system many times faster than in a conventional SCADA. “The ProficyiFIX- iPower system has improved
SCADA system reliability and delivered more efficiency to network management,” said
Martin Walton, CEO of PowerNet. “It was readily accepted by our operators and enabled us to retain our existing RTUs.”
Alarm and event processing are other important monitoring tools. In addition, operators perform controls such as remote opening and closing of circuit breakers. The system assists with a clear, concise display of information. For example operators navigate from a single picture over-viewing the whole power network. From this picture they drill down to individual substation pictures to see detail supported by alarms and events lists.
PowerNet’s SCADA, which handles approximately 20,000 tags, is designed to present critical information in a clear and intuitive way so that operators are not swamped with flashing lights and alarms during a storm that causes outages.
Automated Load Managemen t
“OnDemand” is a distribution load management option for iPower that fully automates operation of the network to optimize the effectiveness and the profitability of electricity supply. At the same time OnDemand ensures operation of the PowerNet system within the electrical constraints of the network.
Results
• Open, standards-based SCADA system that is easily adaptable to the needs of the business
• Fully automated load management to optimize energy purchases and maximize energy sales
• Improved SCADA system reliability
• More efficient network management
• Data management capabilities that deliver a return on investment that would not be possible with conventional SCADA
“ It was important for PowerNet to implement an open, standards based SCADA system.
Whatever we chose had to be easily adaptable to the frequently changing needs of our business. In particular, we wanted to integrate SCADA with our other business systems. iPower has given us that capability
.”
Martin Walton, CEO,PowerNet
38

Considering the above mentioned case studies and the features of the software package the relative points
Very
High(5)
High(4)
Average(3)
Low(2)
Very
Low(1)
39

5.2
Name of SCADA software
Spectrum Power/DMS
Spectrum Power SIEMENS
Power Control System for the energy systems of the future.
Name of company
Siemens
Sinaut (Siemens Network Automation) Spectrum(Applications Spectrum), is a Distributed
Control System, where each application does a specific function.
Following each Server with its function:
UI or MMI: Display and Logging, this is the Human Machine Interface.
DAS/TIF: Data Acquisition System, is the Front End Processor or interface between the
SCADA System and the RTUs or PLCs remotes.
SDM/ADM: Source Data Management, this includes the DBA and the management of data base static and Operational.
RTC/COMM: The real time Communicators are servers to manipulate the data base in real time (alarms, colouring, commands, etc) and is the system buffer.
DBA: Data Base Administrator and HFD (historical and future data).
Expert System: Application Programming Interface.
NA: Network Analysis, application for analysis in the Power Network (short circuit, State
Estimator, Dispatch Power Flow, etc).
DTS: Dispatcher Training Simulator.
Demand Side Management: Optimization.
40

Spectrum Power offers a comprehensive range of functions for requirements in energy generation, network operations management and communications, including:
Supervisory Control and Data Acquisition (SCADA).
Data input and data modelling:
- Data modelling compliant with IEC 61970 using the Common Information Model (CIM)
- Powerful graphics editor
- Parallel multi-station engineering with job management und undo functions
- Powerful online data activation
Extensive communications options with communication protocols
Maintenance and outage management:
- Fault report handling
- Planning and monitoring
- Fault correction
Functions for managing transmission networks:
- State estimation
41

- Load flow calculation or short circuit calculation
- Contingency Analysis
Functions for managing distribution networks:
- Fault isolation and restoration of power
- Load flow calculation
- Short circuit calculation
- Expert system
Functions for energy data management
- Schedule management
- Forecasting
- Archiving
- Reporting
Functions for demand side management
- Load management for electricity and gas
- Water supply management
Functions for electric power producers
- Automatic generation control with load frequency control
- Scheduling applications
Spectrum Power, is based on the installation of more than 1,800 network control systems worldwide.
Whether for traditional utility companies, industrial companies or independent network operators, network control systems from Siemens fulfil extremely diverse requirements in different areas of power generation, transmission and distribution.
Global presence – local expertise
A multitude of factors must be taken into account to design the network control system correctly. Siemens presence in about 90 different countries ensures the reliable operation of the network around the clock.
Competitive throughout the entire life cycle
Siemens trains the personnel’s– either onsite or in our educational center.
42

Spectrum Power™ 4
Distribution Management Applications
The Spectrum Power™ 4 applications formanagement of distribution networks (DMS) provides the following functions:
 Trouble Call System
 Outage Management
 Switching Procedure Management

Crew Management
Benefits:

Effective and efficient operation of the distribution network

Reduction of operating costs, outage times, and lost revenues

Increased supply reliability and service quality

Optimal usage of the network equipment, deferral of network extension

Openness of the outage information stored in the OMS database and accessible via
SQL

Easy integration with other systems (e.g. GIS, SAP, etc.)
Case Study:
An integral solution for Carinthia, KELAG Netz GmbH, Austria
Reliable and flexible system management with 14 redundant servers, 18 UI workstations, 5 MMI servers with 30 terminals and two large display projections.
With the SINAUT Spectrum 4.5.1 network control system, the Austrian distribution network operator KELAG Netz GmbH has successfully upgraded to a centralized, open ended system
43

for system and fault management. This marks the first successful implementation of an incremental data transfer from the GIS and automatic generation of a schematic plan.
The challenge:
KELAG Netz GmbH operates the bulk of the regional distribution network in the Austrian province of Carinthia. Like other network operators in this deregulated market, KELAG Netz
GmbH faces the dual challenge of firstly preserving its competitiveness with reduced equipment and resources, and secondly guaranteeing a functioning power supply with a high standard of quality.
Under these circumstances, the network operator therefore opted to install centralized system management and centralized fault management for the high-voltage and medium-voltage supply networks. Since the hardware and software components previously used for its network control system had already been discontinued or were no longer available, it was a good opportunity to upgrade the system to the current version of SINAUT Spectrum 4.5.1 with up-to-date 3rd party products.
Solution:
Siemens implemented a redundant network control system that meets all the requirements for today and the future. The SINAUT Spectrum 4.5.1 solution runs under Solaris 10 and Oracle
9i and communicates with 200 tele control stations using the IEC 60870-5-101 and -104 protocols.
System management and fault management were implemented centrally as required. In addition to the standard SCADA functions, a further highlight is that for the first time, technical data and geographical information are transferred incrementally from the GIS, thereby enabling a schematic plan for system management to be generated automatically.
The system also offers a wealth of additional functionalities for reliable, costefficient and flexible system management, including outage management system and load flow calculations (EMS/DMS) as well as load forecasting.
Result:
With this modernization measure, KELAG Netz GmbH has increased its productivity.
Downtimes are minimized and the proportion of “energy not delivered” is reduced. And naturally, the end customer also profits from the higher supply reliability.
44

Considering the above mentioned case studies and the features of the software package the relative points
Very
High(5)
High(4)
Average(3)
Low(2)
Very
Low(1)
45

5.3.
Name of SCADA software
OASyS SCADA, DMS, Responder OMS,
ArcFM GIS
Name of company
Televent ( now Schneider Electric)
OASyS DNA Supervisory Control and Data Acquisition System
When the Telvent , OASyS DNA supervisory control and data acquisition (SCADA) system is made the hub of real-time telemetry and control network, it is ready to build a monitoring and control system that meets your needs, today and as the electric distribution network evolves. Built on an architecture using common standards, the Telvent OASyS DNA
SCADA system integrates Telvent products and services with existing tools, third-party software and enterprise systems. Network operators, dispatchers, reliability analysts and managers can operate as a team, all having secure and reliable access to the same pool of real-time information. And, the extensive experience in meeting the demands of utility operations allows to continually identify and implement strategic improvements. The most recent Telvent OASyS DNA SCADA upgrades and enhancements target Smart Grid implementations and the distribution utility requirements of tomorrow. The solution enables utility to realize:
Enhanced network reliability – enabling self-healing network architecture with field proven stability in an increasingly complex distribution network Increased safety – reduces errors with enterprise-wide, real-time data and tools that track and manage changes and report them in response to internal and external review
Proven security – a highly secure system out of the box with a single sign-on implementation; the solution has been evaluated and assessed through the U.S. Department of Energy Idaho
National Laboratories SCADA Test Bed Efficiency across the enterprise – less training required, reduced IT and labor costs, reduced Operating &Maintenance costs Platform for
Advanced DMS – deploy as the core infrastructure for Telvent’s industry leading distribution management system serving as an Advanced DMS for your Smart Grid future.
46

Maintenance: Extensions to the Network Management Console (NMC) – the framework that provides status monitoring and control of different systems/sites, machines and services – now allow this tool to monitor integrated applications and services. The SCADA administrator can define which users have access to specific functions and data.
• Tagging: Group tagging operations and configurable support provide operators with simplified workflow that minimizes user errors.
• Alarming: Analog points can be grouped for common limits; four sets of alarms limits can be activated automatically or manually by system or region.
• Control: The new Rules Validation Engine (RVE) enables ‘rules’ that check and allow/disallow analog, status and multistate commands for configured points.
• Testing: Test Mode alarm suppression reduces unnecessary alarms when field devices are being tested as part of troubleshooting, maintenance, and updates.
• Multi-point operations: Operators can easily group points in the GUI and perform operations such as Alarm Inhibit/Enable and Tagging on this group in a single action.
Data collected through Telvent SCADA integrates seamlessly with other utility software applications, such as our Distribution Management System (DMS) and Outage Management solutions to enable Smart Grid operations. Our OASyS Dynamic Network of Applications
(DNA) product family gives utilities the ability to easily use real-time data from the field in their current toolset, improving daily operations and business and planning decisions.
Security, reliability, innovation, flexibility and responsiveness are the hallmarks of the
Telvent SCADA system.
Advanced Distribution Management System(DMS)
Telvent Advanced DMS provides the most comprehensive network management solution with monitoring, analysis, control, optimization, planning and training tools that all function on a common representation of the entire electric distribution network. By merging distribution management(DMS), outage management (OMS), and supervisory control and data acquisition (SCADA) systems into one secure, unified solution with over 50 advanced functions, it can maximize benefits from a growing abundance of intelligent grid devices, distributed renewable energy, advanced metering, and all things smart grid.
Telvent Advanced DMS presents a consistent, real-time view of the distribution network. It allows system operators, dispatchers, reliability analysts and managers to work as a team —
47

accessing the same as-operated representation of network information. This common visibility allows for efficient and reliable management of grid operations in the face of a diverse, rapidly-changing environment.
Responder OMS
Power outages caused by aging assets, increasingly severe weather and human error are becoming more common in electrical distribution systems around the world. As the market grows more competitive, outages are more costly.
Telvent Outage Management System (OMS) identifies the likely cause of an outage based on input from the call centre, field crews and the advanced metering infrastructure system.
Telvent OMS speeds outage resolution, so power is more rapidly restored and outage costs are contained. It eliminates the cost of manual reporting, analyzes historical outage data to identify improvements and avoid future outages and addresses regulatory and customer demand for quicker responsiveness.
Telvent’s Responder is a GIS-hosted, distributed Outage Management System (OMS) – a complete solution that centralizes functionality through integration of best-of-breed systems.
With its emphasis on implement ability and sustainability, Responder is a simple-to-use OMS that has been developed to be scalable and extensible. It offers users a significant strategic advantage: the ability to deploy OMS with low risk and at reasonable cost. Responder leverages an organization’s investment in ArcFM™ GIS to provide a trouble call analysis and an OMS that offers:
• Call entry and visualization
• Incident creation and management
• Graphical User Interface (GUI) based on ArcMap
• Near real-time operation and fast, efficient updates
• System reliability reports
• History management and reporting
• Crew dispatch and tracking
• Network management (switching, tagging, cuts)
• Support for web and desktop access
• Support for alarms and events
48

• An application built on open standards, which utilize non proprietary programming languages and provide standard interfaces for integration with other systems such as SCADA and telephony
• Additional ad hoc reports
• Support for regions
• Support for gas and water
ArcFM Geographic Information System (GIS)
The key to the electric distribution system of the future—the Smart Grid—is reliable intelligence. Telvent delivers this today, though our ArcFM Enterprise GIS solution for utilities.
ArcFM is based on ESRI’s ArcGIS® technology and is specifically designed for the utility industry, enabling you to model, design and manage your critical infrastructure. By integrating utility data and advanced geographical maps, ArcFM provides a graphical view of your infrastructure that supports cost reduction through simplified planning, analysis and operational response times.
CaseStudy:
1: Enel Distribution Management System, Rome, Italy
Enel is Italy’s largest power company and Europe’s second listed utility for installed generation capacity. Enel operates in 40 countries worldwide, has around 95,000 MW of net installed capacity and sells power and gas to more than 61 million customers.
The challenge
Enel recognized the need for an advanced distribution management system, but lacked the internal resources necessary to create mathematical algorithms to enhance distribution management.
“In the past, some employees tried inventing solutions, but without an adequate technical background it held no scientific value,” explained Christian Noce, DMS integration manager at Enel. “Our employees were spending too many resources trying to create a solution without solid analysis. Without the analysis, the data meant nothing.”
49

The solution
Enel had an established relationship with Telvent and because of its successful past partnerships in a pilot test, decided to enlist Telvent again to implement its distribution management system (DMS). Telvent DMS is a real-time solution that provides complete functionality for the planning, operation and analysis of a utility’s distribution system.
Designed to help complex utilities like Enel, Telvent DMS is packed with a deep, versatile toolset that helps utilities minimize power and energy losses. Additionally, it optimizes voltage profiles and further reduces general costs by enabling peak sharing via demand response (DR) and distributed system and demand response (DSDR).Enel used Telvent DMS to provide a visual, mathematical model of its distribution network, including detailed models for voltage management, micro-generation, frequency variation, DR and other smart grid management data. The utility now has more accurate data and a system that can predict the impact of power outages, generation, and voltage variation.
The results
By implementing Telvent DMS, Enel has experienced significant energy and cost savings.
“Telvent has helped calculate and reduce energy losses giving us a better idea on how we can reduce losses without great investments,” said Noce.
DMS has also helped Enel with supply restoration and network reconfiguration, which reduces time and creates a fast and reliable system for producing results.Enel appreciated the
Telvent DMS open architecture, which allowed for smooth integration with the utility’s
SCADA, GIS and OMS.
The client’s view
“The fact that we were able to integrate Telvent DMS with our existing systems (in particular the SCADA system) has proven to be one of the best features yet, “Christian Noce, DMS
Integration Manager
50

Considering the above mentioned case studies and the features of the software package the relative points
Very
High(5)
High(4)
Average(3)
Low(2)
Very
Low(1)
51

5.4
Name of SCADA software Name of company
Distribution Management System Ventyx (now ABB)
Ventyx, an ABB company, is the world’s leading supplier of enterprise software and services for essential industries such as energy, mining, public infrastructure and transportation.
Ventyx solutions bridge the gap between information technologies (IT) and operational technologies (OT), enabling clients to make faster, better-informed decisions in both daily operations and long term planning strategies.
Distribution Management Systems provide access to critical system data and functions to a large number of users, thereby:
 Increasing operational efficiencies with a common working environment for distribution SCADA, outage management and network applications.
 Eliminating the costs to build, maintain and coordinate multiple network models.
 Improving understanding of the current state of network, enhancing operational safety and decision making.
 Reducing the impact of outages by locating and isolating faults faster.
 Reducing demand and system losses without affecting customer load.
 Improving workflow through a single source of data and information.
 Enabling significant time savings by reusing large portions of existing data.
 Allowing hundreds of users across the enterprise to view and query outage and operational information.
 Providing access to on-line operational data for improved decision support and more efficient use of resources.
52

Key Capabilities:
Distribution SCADA: Improve the information made available to operators, field crew personnel, customer service representatives, management – and ultimately end customers – with a real-time information system for total network monitoring and control of electric power systems.
Network Applications: Achieve optimum network utilization at all times using advanced network functions that provide operators with the analytical tools to make informed decision and manage the network effectively.
Outage Management System: Restore supply faster and more efficiently with a single, integrated platform that enables hundreds of users to simultaneously access information about customers, system status and resources.
53

Case Study :
: Reliance Infrastructure
 Industry: Energy
 Location: India
 Employees: 8300
 Annual Revenue: $2.93 Billion USD
As India's largest private power distributor, Reliance Infrastructure Limited (R Infra) energizes two out of every three homes in Delhi and Mumbai.
Business Impact Summary
As India's largest private power distributor, Reliance Infrastructure Limited (R Infra) energizes two out of every three homes in Delhi and Mumbai. In an environment notorious for power losses, efficient electricity distribution networks represent the means to achieve higher reliability and meet demand growth. Using an integrated Network Manager™ SCADA and Distribution Management System (DMS) from Ventyx, an ABB company, R Infra has applied the state-of-the-art technology to deliver higher availability, protect and extend asset life and significantly mitigate outages downtime—planned and unplanned. The ongoing modernization of the R Infra power distribution networks with Ventyx solutions has since contributed directly to a reduction of distribution losses to 12 percent, the lowest in the country.
The Company
Reliance Infrastructure Limited is India’s leading private utility with presence across the energy value chain, from generation, transmission and distribution to engineering, procurement and construction (EPC) and trading. A part of Reliance Group, Reliance
Infrastructure is India’s largest infrastructure company. It distributes more than 36 billion units of electricity to 30 million consumers and generates 941 MW of electricity from its power stations.
54

The Challenge
Reliance Infrastructure (R Infra) generates transmits and trades electricity from its power stations. As the leading private utility in transmission and distribution in India, it distributes power to more than 30 million consumers across India, including Delhi and Mumbai. As the demand growth for electricity consumption increased over the years, R Infra's biggest challenge to meeting this demand has centered on achieving high availability of power.
Traditionally, distribution losses topped 30 percent, necessitating a focused response to improve the performance of the last leg in R Infra's power supply chain.
The distribution operations of R Infra's power supply chain has since driven the singular goal of reducing outage downtime—both planned and unplanned. The strategies identified to achieve success were clear:
 Improve outage restoration
 Reduce load shedding
 Maintain voltage profile consistency
With significant growth opportunities and market presence at stake, R Infra sought a proven and robust enterprise solution for its control room operations with advanced distribution management applications and enhanced human machine interface (HMI) features. R Infra additionally sought to increase visibility and control of its distribution network by procuring the installation of feeder remote terminal units (FRTUs) at its ring main units, which comprise a secondary distribution system designed to supply uninterrupted power through alternate sources. In parallel with the planned operational improvements, key business processes such as the ones used to integrate with the intrastate Availability Based Tariff
(ABT) system—the frequency-based pricing mechanism for electric power in India—were targeted for optimization.
The Solution
With previous in-house experience implementing SCADA systems, R Infra modernized its distribution operations with a highly integrated Network Manager SCADA and DMS solution from Ventyx. It delivered real-time monitoring and control alongside advanced network applications to RInfra's distribution network, promoting an able environment to address its key challenges.
55

Complementing full SCADA functionality, the enterprise solution incorporated advanced distribution applications to optimize network utilization, among them fault location, isolation and system restoration (FLISR), load flow calculations and volt-var control. The modern
SCADA solution provides a more accurate representation of the as-operated electrical distribution network while robust distribution capabilities have improved the accuracy and quickness in the fault-zone determination, isolation and restoration of RInfra's low voltage distribution network.
In addition, the solution was designed with an islanding scheme intended to mitigate power disturbances by enabling each distribution point to receive power from either direction in the case of a fault. The advantage of this multi-directional power flow design lay in the high reliability delivered by multiple power sources. FRTUs have also been installed to monitor the fault indications along the sections, facilitating faster identification of faults and power restoration on non-faulty sections through the alternate sources.
Finally, the solution was integrated to other enterprise systems such as RInfra's geographical information system (GIS), which enabled more efficient utilization of the DMS capabilities, and their State Load Dispatch Center (SLDC), which facilitated the implementation of the
ABT mechanism and the optimization of its related business processes.
The Result
"The availability of important real-time information from generation, transmission and the distribution network in one centralized location has enabled quick decision making during major grid failures and other faults," said Reliance Infrastructure Head of SCADA
Maintenance Bhushan R. Chaudhari. "The system as a whole is highly reliable. Our operations team is fully dependent on the SCADA system for their daily operations and network analysis."
The user-friendly displays at operator workstations have further helped system control engineers operate geographically scattered elements of the distribution network with ease.
Significant operational gains achieved in RInfra's distribution network include:
 Reduced outage downtime by 45%
 Reduced overall distribution losses to 12%--the lowest in the country
 Reduced the Customer Average Interruption Duration Index (CAIDI)
56

 Extended asset life by protecting generation plants at Dahanu, Maharashtra from tripping during major grid disturbances, a benefit resulting from the powerful combination of the automatic load shed application with the islanding infrastructure scheme
 Improved operational excellence and work processes
Collectively, the integrated Network Manager SCADA/DMS solution from Ventyx has directly met the overarching challenge to increase availability by reducing the downtime of outages. RInfra continues to derive value from the broad Ventyx portfolio of operational management, control and IT solutions. Planned upgrades look to leverage next generation distribution and control applications, smart design and optimization tools.
Considering the above mentioned case studies and the features of the software package the relative points
Very
High(5)
High(4)
Average(3)
Low(2)
Very
Low(1)
57

5. 5.
Name of SCADA software Name of company
Survalent Survalent Technologies
Survalent Technology makes real-time operational intelligence and control easy. For over five decades, Survalent has helped more than 400 utilities use operational data to increase reliability, efficiency and customer service.
With the following proven and reliable solutions, utilities transform data into actionable intelligence with Survalent:
Smart SCADA: Supervisory Control and Data Acquisition (SCADA)
Smart OMS: Outage Management System (OMS)
Smart DMS: Distribution Management Systems (DMS)
Smart DA: Distribution Automation (DA)
Smart DS: Demand Response (DR)
Smart SA: Substation Automation (SA)
SurvCentral - Mobile Applications
Survalent Technology partners with utilities across the globe to create mission critical solutions that will achieve the promise of the Smart Grid.
SmartSCADA is a software automation solution to provide real-time control and data acquisition for utility operations.
Master Station
Base SmartSCADA software includes: no limits for status points, control points, analog points, or communication lines. SmartSCADA software includes SCADA Explorer database editing application and WorldView graphical user interface
The Survalent Master Station is fully scalable:
58

-redundant Master Station
-redundant Master Station
-redundant Master Station
-standby Master Station
HMI
SmartOMS is a fully integrated, flexible and feature-rich Outage Management System
(OMS). It is designed to run on the SCADA host, with a user interface built into the
WorldView operator interface. SmartOMS is therefore fully redundant along with the rest of the SCADA system.
Automated Data Entry
SmartOMS is highly automated and yet very interactive in the management of calls and outages. The purpose of this is to help the dispatcher as much as possible, but still give him complete control and all final decisions.
Call Analysis
Call backs
IVR and Caller ID
WorldView Map Interface
Crew Management
Switch Orders and Guarantees
SCADA Events and Operations
AMI
Smart DMS is fully integrated on the Survalent Smart SCADA platform, enabling a widerange of standard
59

SCADA features such as multiple redundancies and a single user interface for both DMS and
SCADA.
The following features are standard on every SmartDMS system:
Network Model
Topology Processing
Load Flow
Security Analysis
SmartDMS Studies and Reports are accessible via menus in the WorldView map window.
Each study and report window contains a pushbutton that allows the dispatcher to obtain a hardcopy of the results.
-Circuit Study
-Fault Load Transfer Recommendations patch Study
Reports:
60

SmartDA is a fully integrated, flexible and feature-rich Distribution Automation (DA) solution. It is designed to run on the SCADA host, with a user interface built into the
WorldView operator interface. SmartDA is therefore fully redundant along with the rest of the SCADA system.
There are two applications that fall under the SmartDA product category:
Power Factor Control
Dynamic Voltage Regulation (DVR)
SmartDR is a fully integrated, flexible and feature-rich Demand Response (DR) solution. It is designed to run on the SCADA host, with a user interface built into the WorldView operator interface. SmartDR is therefore fully redundant along with the rest of the SCADA system.
There are three applications that fall under the SmartDR product category:
Advanced Metering Infrastructure (AMI) Interface
Load Curtailment
Dynamic Voltage Reduction
Case Study:
1.Survalent Technology Commissions New SCADA System For The City Of Shasta
Lake, California
Survalent Technology, the most trusted provider of smart grid solutions for the control room, announced today that it has commissioned a new Supervisory Control and Data Acquisition
(SCADA) system at the City of Shasta Lake, California.
The City of Shasta Lake is a load serving entity and distribution provider. The City operates four electrical substations providing retail electric service to customers located within the
City's corporate limits, as well as certain adjacent areas and serves approximately 4,453 retail customers, of which 4,100 are residential. The City of Shasta Lake is a member of California
Municipal Utilities Association (CMUA).
61

The new system features Survalent’s highly available, open-architecture system based on
Windows Server 2008. It includes several of Survalent's open system applications, including:
WorldView, SCADA Explorer, Command Sequencing, IED Wizard and Control Panel,
SCADA Add-In, Remote Alarm Annunciation, Short Term Load Forecasting and Multi speak Interface to the Tantalus AMI system.
"We are pleased that the City of Shasta Lake has joined the family of Survalent system users by replacing their legacy system with a state-of-art new SCADA system. The City has decided to select a system with an open architecture which provides new possibilities in the future for interoperability with the other enterprise applications such as the AMI and GIS systems," states Mike Roth, Vice President of Sales for the Western United States.
2.Survalent Technology Commissions New SCADA System For Cornwall Electric
Survalent Technology, the most trusted provider of smart grid solutions for the control room, announced today that it has commissioned a new Supervisory Control and Data Acquisition
(SCADA) system Cornwall Electric.
Cornwall Electric supplies electricity to over 23,800 customers in the City of Cornwall, South
Glengarry, South Stormont, and the Ontario portion of the Mohawk Territory of Akwesasne.
It is a wholly owned subsidiary of Fortis Ontario, headquartered in Fort Erie with operations in distribution and transmission serving approximately 65,000 customers.
The new system features Survalent’s highly available, open-architecture system based on
Windows Server 2008. It includes several of Survalent's open system applications, including:
WorldView, SCADA Explorer, IED Wizard and Control Panel, SCADA Add-In, Command
Sequencing, Remote Alarm Annunciation and Event Data Recording.
“We are pleased that Cornwall Electric (Fortis Ontario) has selected Survalent Technology to replace their existing SCADA system,” states Paul Stirpe, Vice President of Canadian Sales.
“Cornwall is making several system upgrades to take advantage of smart grid technologies, as well as integrating their system back to the main Fortis Ontario control system, which is also a Survalent system. The system offers an easy way to leverage the real time mission critical data from the field and share this information with other software applications to in order to make them more valuable.”
62

Considering the above mentioned case studies and the features of the software package the relative points
Very
High(5)
High(4)
Average(3)
Low(2)
Very
Low(1)
63

5.6.
Name of SCADA software Name of company
LYNX GillamFei
GILLAM-FEI S.A.
has expertise for more than 25 years, in development and design of
SCADA/DMS systems, with its LYNX application suite . This package is now well recognised throughout Europe and Asia : mainly in France, Belgium, Switzerland, Cyprus,
Thailand and Indonesia. Its presence in the remote control systems activity inter-operating with Remote Terminal Units from various manufacturers has proved its worth.
Gillam-FEi SA offers its own application software package SCADA/DMS LYNX and its different modules to match with customers’ requests.
The LYNX software is an application suite for the monitoring and remote control of RTU’s, whatever produced by Gillam-FEI or other manufacturers. LYNX enables data acquisition, data processing (including the analysis of any event affecting grids as well as data archiving) and its handling. Moreover, LYNX is also composed by several Distribution Management
System modules like Dynamic colouring, Quality Module, Load-Flow Calculation module, Simulation module, the Fault Detection module, Isolation and Energy restoration plans, Load Balancing module and Loss Minimization.
The LYNX software is a SCADA application dedicated to the remote control of several types of networks : mainly electricity, gas and water distribution networks. Indeed, LYNX is an object-oriented application, allowing to manage different types of objects for different types of networks. The system allows from a unique database to manage these different techniques simultaneously. The definition of users rights is managed partly from the technique associated to it.

For electricity distribution networks : objects such as circuit breakers, disconnectors, bus bars and any other object related to electrical networks

For the remote control of Middle Voltage and Low Voltage electricity distribution in the airports : objects specific to this type of application such as protection relays and lighting areas are added and managed by our application.
64


For water distribution networks : water extraction, wastewater treatment plants. In addition to the functions specific to this type of processes (extraction, filtering, ozonation, distribution), the system can also perform the control of the high voltage supply for this type of power plant.

To control remotely hydroelectric power plants : valves adjustment, adjusters positions, screen raking, regulation of turbines, etc…)

To control remotely gas networks: valves, pressure transducers, flows, etc…
Strengths of LYNX SCADA/DMS application
 sClient - Server architecture

UNIX/LINUX operating system for servers ; Windows for operators workstations
 Hardware supplied from state of the art manufacturers(HP/Compaq…) : servers, workstations, laptops, laser printers, dot-matrix printers

X11 graphical interface

RDBMS for information storage and retrieval: POSTGRESQL, 100% SQL database without any associated license fee with standard ODBC and Oracle interfaces available.

Data transfer through ODBC links between Lynx and office standard applications
(Customer Care application and Billing application)
 Standard protocols management with RTU’s: ISO/IEC 60870-5-1, ISO/IEC 60870-5-
3, ISO/IEC 60870-5-4,

DNP 3.0, Modbus, HNZ PA4, PA20, JBUS time stamped or not, S-BUS, SNMP,
TCP/IP…

IEC 61850 Interface
 Proprietary protocols management with RTU’s : TELEGYR (TG709, TG800, TG809,
TG065), SIEMENS, ABB (RP570, RP571), SAIA

Exchanges between control centres : ICCP Tase2 and TCP/IP

Object Oriented Technology

Possibility to manage several hundred thousands of objects/points

Modular application / possibility to perform upgrading

Interoperability with other relational database (Oracle,…)

Possibility to manage and import existing database
65

o SEL Lausanne : import of LS 3000 o SIG Genève : import of LS3200 and SINAUT SPECTRUM o SIM La Chaux-de-Fonds : import of LS 2000 o SI Lutry : import of ABB (Micro-Scada) o ALE Liège : import of TG8000

Recovery of map files (in DXF format) from Autocad

Interface with market software modules (software for long term network planning)

WEB Interfaces for data consulting and controlling

Remote maintenance possibility

Multi-screen operating stations

Redundant acquisition and application servers (in a hot stand-by mode)

Archiving server

Redundant LAN Ethernet network

On the field laptops

Decentralized operator stations

Interface with other remote control systems

External synchronisation (GPS, DCF77,...)

Alphanumerical displays management

Screen wall
SCADA Features

Software functional redundancy for SCADA and DMS functions,

Full and User Friendly Graphic user interface,

User friendly tools for online display generation and database management maintenance,

Support for high level programming languages,

Involve wideband communication system for data transfer,

Integration of energy meters with RTUs / Data Concentrator,

Modbus & IEC 870-5 protocols and many others protocols,

Network operations Forecast Management,

Customer Management,(MV/LV) Alarm handling,

Tagging, trending,
66


SOE,

Real time data acquisition & calculations.
DMS/EMS Features

Load flow calculation,

Loss minimization via feeder reconfiguration,

Load Balancing,

Simulator with offline environment

Outage Management ( with statistics like number of de-energized customer, average outage time per customer)

FDIR (Fault detection, Localisation, Isolation and Restoration),

State Estimator
Case Study:
1: Gillam-FEi Deliver Electricity Distribution Control System to Services Industriels de
Geneve (SIG) Utility
Services Industriels de Geneve is the Utility for the Geneva area and delivers water, gas, electricity and telecommunication network access for more than 400,000 citizens in a high density area of more than 240 km2. SIG produces also more than 30% of the electricity needs of the area thanks to their hydraulic power plants, which utilize a control center that was also provided by SchlumbergerSema. With more than 1,450 employees, SIG is one of the biggest
Utilities in Switzerland.SIG provides electricity transmission and distribution services to more than 250,000 residents in the Geneva, Switzerland, area.
The new energy control system encompasses powerful network simulation capabilities, which enable SIG to optimize transmission and distribution grid operations, and achieve better matching of power generation with consumption demand. It will also enable the utility to improve the quality of electrical distribution, and to simulate and prepare for various recovery scenarios in the event of network failures.
The supervisory control and data acquisition (SCADA) system includes application programs for efficient power distribution, as well as communication with remote terminal units located
67

in substations and with control centres in other geographic areas.
"Having a single system for the control of both the transmission and distribution networks provides significant savings in training, operation, maintenance and data engineering," stated
Meyer Bengio, president of Energy & Utilities, SchlumbergerSema. "The fault detection capabilities of the system will not only minimize outage times to improve service quality, but also dramatically speed up decision-making processes."
"In the changing competitive context of deregulation, the LYNX SCADA/DMS software integrates the management system with state-of-the-art databases and large-scale IT technologies to provide SIG with the tools to deliver high-quality products and services for its customers," commented Richard Creppe, SCADA sales manager for Gillam-FEi.
Considering the above mentioned case studies and the features of the software package the relative points
Very
High(5)
High(4)
Average(3)
Low(2)
Very
Low(1)
68

5.7.
Name of SCADA software Name of company e-terra distribution Alstom e-terra distribution Integrated Distribution Management System (IDMS) combines multiple applications into a single, integrated application environment. This gives an increased visibility of the system and provides with more actionable information. e-terra distribution responds to the needs for:









Grid optimization
Outage time reduction
Situational awareness
Asset utilization and optimization
Crew management and safety
Smart meter integration
Distributed resources integration
Electric vehicles integration
Demand response integration
The e-terra distribution suite of applications combined with SCADA provide network management functionality to give dispatchers and network operators the tools they need to make the most effective use of network capabilities. The base application for all the e-terra distribution solutions is Network View, a unified operating environment that displays the status of the electrical network in both geographic and schematic formats, using a real-time network operations model created directly from the Asset Management System (GIS). The other applications in the e-terra distribution suite can be seamlessly integrated with the base application to complete solutions that meet your evolving needs.
69

The additional applications that can be included in an e-terra distribution solution are:
● Network Outage Management – analyze, visualize, track and coordinate all outages
● Network Analysis –unbalanced distribution power flow, protection validation and fault location
● Network Optimizer – feeder reconfiguration, system restoration and Volt/Var optimization tools
● Network Switching Operations – creation of Switching Orders and Safety Documents for planned and unplanned outages
● Network Simulator – operator/dispatcher training and performance testing
● Network Operations Archive – historical data recording e-terra distribution is an Integrated Distribution Management System (IDMS) that has been designed to bring together all of the control room tools necessary for real-time operations in one user interface. The user has seamless navigation between applications and single entry of operational actions like tags. The challenges of maintaining synchronization between network connectivity models of disparate applications, such as Outage Management and realtime power flow, are removed. An interface architecture utilizing secure SOA facilitates integration with other systems across the enterprise independent of the vendor or internal product structure.
70

71

Case Study:
1. Alstom’s Integrated Distribution Management System Selected for Maui Smart Grid
Project
About the Maui Smart Grid Project
The Maui Smart Grid Project is evaluating smart grid technologies that can help Maui
Electric Company and its customers reduce peak energy demand, improve service quality, inform consumer energy use decisions, and integrate renewable energy. This demonstration project will utilize distribution circuits in South Maui and up to 200 customer volunteers that can receive in-home smart grid technologies. The project is funded by the US DOE
Renewable and Distributed Systems Integration (RDSI) program and is part of a nationwide set of demonstration projects. Data from the Maui project will be compared with results of similar initiatives to inform future smart grid decision making
Alstom Grid, the global expert in electrical grid management systems, has been selected to provide its e-terra distribution Integrated Distribution Management System (IDMS) for Maui
Electric Company’s (MECO) Smart Grid demonstration project (“Maui Smart Grid Project”).
This project is funded by the U.S. Department of Energy and is co-led by the Hawaii Natural
Energy Institute at the University of Hawaii.
Alstom’s IDMS suite of smart distribution applications will integrate information from the smart grid network to improve monitoring and control of MECO’s distribution system and distributed energy resources (DER).
"The Maui Smart Grid demonstration project is a critical component to reducing our state’s dependence on imported oil, integrating more clean energy and improving the service we provide to our customers," said Maui Electric Company’s President Ed Reinhardt. "Alstom's
IDMS applications will play a significant role in helping our customer volunteers experience first-hand the benefits of a smarter power distribution system. We look forward to having the system up and running, and working with Alstom experts to make this demonstration project a successful best practice for similar initiatives across the country."
“Hawaii has set an ambitious goal of generating more than 70% of its electricity from clean and renewable sources by the year 2030,” commented Karim El Naggar, Vice President of
Alstom’s Network Management Solutions business. “By deploying new distribution and home automation technologies, MECO will gain hands-on experience in maintaining grid reliability that is invaluable as the state transitions to a cleaner energy future. Alstom is proud
72

of our role in this project in ushering in the era of a smarter and more reliable electric power grid.”
Alstom’s IDMS suite of smart distribution applications will be deployed to improve grid selfhealing, power quality and energy efficiency for enhanced customer satisfaction. The IDMS platform will be integrated with smart grid data to provide MECO’s dispatchers with enhanced visibility into their distribution grid operations and control over distributed energy resources.
Considering the above mentioned case studies and the features of the software package the relative points
Very
High(5)
High(4)
Average(3)
Low(2)
Very
Low(1)
73

6.1 Conclusion:
The complete SCADA implementation in distribution utilities will definitely help the Indian power sector in (i) to reduce the huge losses in the sector, (ii) to bridge the demand-supply gap, (iii) to improve system reliability and consumer satisfaction and (iv)paving the way for implementation of Smart Grid in India.
A Newton Evans study will show the importance of SCADA packages towards Smart Grid dream, (see Figure 7).
The power industries, SCADA, will continues to thrive, especially in the growing intelligence arena, as noted in the Newton-Evans study. The future for SCADA is bright. Control roombased systems typified by EMS, SCADA and DMS,GIS will continue to be the key systems for control and monitoring of electric power operations—all the while undergoing frequent changes and incorporating additional levels of data. The state of SCADA is certainly in flux.
74

6.2 Limitations of study:
The study was done with the for the distribution utilities in different parts of the world who have been using various SCADA software packages. But the data of what they have benefitted from the implementations of the particular distribution SCADA package (in terms of AT&C loss reduction or improved reliability) could not be used for comparison as these parameters depend on various other factors.
The actual cost of the software packages was not available in the public domain and could not be used to compare as the package properties as software features vary according to geographic and network conditions.
More information about their old SCADA packages and new solution could have been obtained by analysis of the utilities performance owing to the SCADA package they used.
This study is just an analysis of the SCADA software packages present in the market and does not propose to suggest any solutions. Identification and evaluation of SCADA solutions and their features will be up to the distribution utility according to its needs and conditions. But it is important to know about all the available and appropriate options in detail, which is exactly what this report tries to achieve.
75

6.3 Findings & Recommendations :
Beyond a look at how important SCADA is in the care and feeding of power systems, the
Newton-Evans Market Research study reveals some things about SCADA.
In the European and American market, among mid-size system (SCADA/DMS) vendors mentioned in the study, ACS leads the way overall with 18 mentions, followed closely by
Survalent with 17. Larger systems installations (EMS/SCADA) were represented by AREVA with 14, OSI with 12, and Siemens and GE tied with 10 (see Figure 8 ).
76

From the above Newton Evans Market study, and from the study from the features provided we can figure out that out of the twelve SCADA solution discussed in the report a few stand out i.e. ACS, Survalent, iFix by GE, Eterra by Alstom, Spectrum Power by Siemens and
DMS by Televant.
For the Indian Distribution Market, for Automation, SCADA/DMS implementation point of view, what so far stands out is the companies that have so far started with the implementation of such features have bought the distributed software i.e. a software package for automation from one different vendor, a DMS package from a second vendor and a PMS package from the third vendor. This causes many different problems in integrating all the packages all together and to control them through one source.
Even though it is a starting and experimentation phase and initial costs are very high, what the study suggests is that if a single vendor is utilized all together installation and integration of DA, SCADA,DMS,OMS,GIS is all together easy and less costly.
Televant, ABB and Siemens already have a firsthand experience in implementing in Indian conditions. Dongfang also has some DMS projects in pipeline.
From the comparison of software features Figure 9:
6
7
4
5
1
2
3 iPower for iFix
Spectrum Power
Oasys
SCADA,DMS,OMS
4 3 4
DMS by Ventyx
Survalent
5 3 3
5
5 4 3
5
5
4
4
4
LYNX 4 3 3 e-terra distribution 4 4 4
3 3
4 3
4 3
4 3
4 3
4 3
4 3
3
5
5
3
4
3
3
4
4
4
3
4
4
5
77
27
29
23
27
23
30
26

The above analysis provides that for the distribution utilities, the most promising packages are Survalent & E-terra by Alstom respectively. Survalent has been a huge success story in the American market. It provides SmartDA, Smart SCADA, SmartDMS, SmartOMS,
SmartDS, SmartSA. All these software packages have enormous features and can be purchased separately for installation at various stages or the utilities can purchase the whole package for complete distribution change. E-terra all the more has same packages and features as Survalent and has been used by many distribution utilities.
The utilities which want to be on the safer side can to go for the DMS package of Televant, it is a complete software package for SCADA implementation with integration with
Distribution Automation, DMS,OMS,GIS packages and they already have shown results through implementation in more than two cities.
78

6.4 Scope & Opportunities of SCADA in Indian Power Distribution Utilities (R-APDRP
Part A, Smart Grid) and Their Present Status.
Substation automation has taken centre stage on the distribution side of power business in
India. The Indian State’s R-APDRP (Restructured Accelerated Power Development and
Reforms Program) has provided the thrust and focus on electric power loss reduction through reliable automated systems and adoption of information technology in the area of energy accounting. The backbone for sustaining the R-APDRP program is underscored by successful upgrades of legacy-system based substation automation. In the process, protection and automation of power supply systems have attained high priority.
For the electrical distribution part of the business, improvements in technology are evident in the functional capabilities and value proposition offered by Electric SCADA (Supervisory
Control And Data Acquisition Systems), in terms of infusion of intelligence into grids, increasing substation automation, real-time demand response pricing, and also complex forecasting models. SCADA is now viewed as an essential component to manage the smart grid. The transmission and distribution restructuring requires SCADA to become an integral part of the unique business processes of the electric power market to seamlessly unify the separate domains of generation, transmission, and distribution. Intelligent field devices and the resultant available data requirements for SCADA in transmission and distribution substations drive demand.
On consumption side of power business, the State owned Power Grid Corporation of India’s
(PGCIL) is driving a power evacuation program, estimated to be $ 10 billion. Substation control devices center on the area of protection. It is not just the electromagnetic relays that have to give way to microprocessor based numeric relays. It now encompasses intelligent electronic devices (IEDs) Sequence Event Recorders (SERs), Remote Terminal Units
(RTUs), transformer tap changers, and such others. All these devices and units with essential communication capabilities facilitating interconnectivity and links through local area network and HMIs makes the essential transformation from the legacy systems of yesteryears.
Centralized Load Dispatch Centers have come into being, facilitating greater visibility across the entire operative range of substations or cluster of substations. It is no more a challenge with modernized SCADA in place to control circuit-breakers in remote areas and facilitate seamless load and fault management.
79

The focus of Restructured Accelerated Power Development and Reforms Programme (R-
APDRP) is on the actual demonstrable performance in terms of AT&C loss reduction, establishment of the reliable and automated sustainable systems for collection of base line data, adoption of information technology in the areas of energy accounting, consumer care and strengthening of Distribution network of State Power Utilities.
Projects under the scheme shall be taken up in two parts. Part-A shall include the projects for establishment of baseline data and IT applications for energy accounting/auditing & IT based consumer service centres. Part-B shall include regular distribution strengthening projects. The activities to be covered under each part are as follows:
Part – A: It includes

Consumer Indexing, Asset Mapping

GIS Mapping of the entire distribution network

Automatic Meter Reading (AMR) on Distribution Transformers & Feeders

Automatic Data Logging for all Distribution Transformers and Feeders

SCADA/DMS in big towns / cities (with population > 4 lakh & energy input > 350
MU)

Feeder Segregation / Ring Fencing

Establishment of IT enabled customer service centres

Establishment of the Base Line data System
IT IMPLEMENTATION AGENCY has been assigned
 To Implement the IT related schemes in the defined area/ feeders as per scope and terms and condition stipulated by the Utility/ IT Consultant.
 Supply, install, commission necessary infrastructure ( hardware, software, network, etc.)
ITIAs have been divided into
SI — System integrator
GSP – GIS Solution Provider
MDASP — Meter Data Acquisition Solution Provider
NSP – Network Solution Provider
The present status of R-APDRP Part A scheme is as under:
80

 Under Part-A of R-APDRP, 1,402 projects at an estimated cost of Rs.5,196.53 Cr have been approved for 29 States/UTs and Rs.1,578.67 Cr have been disbursed.
 Part-A SCADA projects for 62 towns of 14 states have also been sanctioned at an estimated cost of Rs.1426.93 Cr and Rs.276.30 Cr have been disbursed.
 Barring one state (Haryana), all Part A projects have been awarded and are under implementation.
Use of international standards has also kicked in. India has been one of the quickest to adopt the international standard for substation automation systems - IEC 61850 standards, considering that they were published in this decade. The suite of standards defines communication between devices in the substation and related system requirements, supports all substation automation functions, and their engineering. IEC 61850 suite of standards’ impact is not limited to design and technology aspects; it has a bearing on the procurement process as it brings automation suppliers and solution providers on a common platform, facilitating comparison and competitive bidding. The ongoing technology adoption, particularly use of international standards, is bound to provide a greater fillip to the modernization program on the transmission and distribution front in India, especially considering the convergence of SCADA with distribution and outage management. The substation electric equipment suppliers have been traditionally the domain of global automation suppliers, such as ABB, Siemens, and Areva T&D . With the deployment of international standards, electric power SCADA suppliers have become integral to substation orders with most transmission and distribution companies bundling the requirements as part of their modernization programs.
For the first time in the country two State-owned electric utilities -- AP Transco, in Andhra
Pradesh, and Tamil Nadu Electricity Board -- have undertaken to develop and install
Distribution Automation system for Hyderabad and Chennai respectively.
The Chennai City Distribution system, covers over 95 stations spread over in Chennai. The system, executed by ABB, has been operational since November 2000 and was implemented at a cost of Rs 19.2 crore.
81

The Hyderabad installation integrates SCADA with DMS functions for effective monitoring and control of the electricity distribution network for the twin cities of Hyderabad and
Secunderabad.
Spread over an area of 1,500 sq km, the network comprises about 20 EHV stations and 110
33/11 kV stations, serving over a million consumers. With major part of the work complete, the system, supplied by ABB India on a turnkey basis.
BESCOM
 The Bangalore Electricity Supply Company (BESCOM) implementing aRs 1 billion pilot project in electronic city, BANGALURU.

It will cover 19,441 consumers with a connected load of 120MW.

Key enabling features:

Ongoing IT projects such as R-APDRP

Automation of the 11 kV network in BANGALURU

Support from the government

Key functionalities:

Development of AMI

Online condition monitoring of distribution transformers

Peak management

Outage management

Integration of renewable energy
MESCOM
•
The Mangalore Electricity Supply Company (MESCOM), has implemented a pilot project in MANGALORE at an investment of Rs 495,000.
•
The utility modified the existing static meters at distribution transformers by adding a smart node.
82

The project significantly improved the metering and load control of all mixed loads; reduced load shedding at feeder level; help monitoring energy usage with greater precision; and controlled aggregate consumer loads including street lighting systems.
Even private sector utilities have started taking the first steps to use SCADA systems to optimise power distribution. NDPL & BSES is in the process of modernising its existing system. The CESC has also installed a SCADA system.
NDPL( North Delhi Power Limited), a distribution company in north Delhi has implemented advance state of art distribution automation and SCADA technologies.
SAP as ERP solution
Central SCADA control room : powered by Sinaut Spectrum Power, Siemens
DMS: powered by Sinaut Spectrum Power, Siemens
OMS: powered by PowerOn, by GE
BSES ,(RInfra Company), providing distribution in South Delhi and Mumbai have also taken up advanced automation & SCADA technologies to provide reliable and quality supply.
Central SCADA: powered by Network Manager, Ventyx, ABB
DMS/OMS: powered by DMS, Ventyx, ABB
Definitely the Indian utilities are moving towards smarter utilities of the future and SCADA implementation throughout will be the stepping stone towards the greater result.
83

Bibliography
1.
A G Bruce, Member IEEE ,Trans Power NZ Ltd, “RELIABILITY ANALYSIS
OF ELECTRIC UTILITY SCADA SYSTEMS” 7803-3713-1/1997 IEEE
2.
ANSMEEE C37.1-1- 1987, IEEE standard definition specification and analysis of systems used for supervisory control, data acquisition and automatic control.
3.
I.Roytelman, V.Ganesan¸ April 2000, "Coordinated Local and Centralized Control in Distribution Management Systems", IEEE Transaction on Power Delivery, vol.
15, No. 2, 718-724.
4.
J.Carr, L.V.McCall¸ July 1992, "Divergent evolution and resulting characteristics among the world’s distribution systems",
IEEE Transaction on Power Delivery , vol. 7, No. 3, 1601-1609.
5.
Uluski Bob, Electric Power Research Institute, “ Distribution Management
Systems” at
CRN Summit Cleveland Ohio July 20, 2011.
6.
IEEE Working Group”Smart Grid for Distribution Systems:: The Benefits and
Challenges of Distribution Automation ((DA)) ((Draft Version 2)) White Paper for NIIST”2007.
7.
Dr. Graham Ault “UK Research Activities on Advanced Distribution Automation” at IEEE PES General Meeting 2005 – San Francisco, June 2005
8.
Pahwa and J. K. Shultis, “Assessment of the Present Status of Distribution
Automation”, Engg. Experiment Station, Kansas State Univ., Manhattan, KS,
Rep. 238, 1992.
9.
K. Ghoshal, “Distribution Automation: SCADA Integration is Key”, IEEE
Computer Applications in Power ,1997, pp. 31-35.
10.
The World Market Study of SCADA, Energy Management Systems and
Distribution Management Systems in Electric Utilities: 2010-2012, Newton
Evans, Jan 2011, Pages: 335http://www.newton-evans.com/reports/
11.
Availability of a SCADA/OMS/DMS system — A case study International
Standard IEC 61968-1 First Edition 2003-10
12.
Model Technical Specification (MTS) document by Power Finance Corporation
(PFC) for SCADA/DMS implementation under RAPDRP Part A.
13.
IT task force report for power sector submitted by IT task force.
84

14.
Report about existing national structures and activities, energy targets, foresight studies and their impact on ERA-Net Smart Grids by Smart grid Era Net
Deliverable 4.2.1
15.
Report on “Performance of State Power Utilities for the years 2007-08 to 2009-
10” by Power Finance Corporation Limited
16.
Implementation of Accelerated Power Development and Reform Programme
Ninth Report by Ministry of Power
17.
http://ieeexplore.ieee.org/xpl/articleDetails.jsp?arnumber=5638912
18.
http://www.cired2011.org/documents/CIRED2011-Session1-Executive-
Summary.pdf
19.
http://www.researchandmarkets.com/reports/2022467/distribution_automation_20
12_2016_technologies
20.
Electricity distribution companies by country http://en.wikipedia.org/wiki/Electricity_distribution_companies_by_country
21.
http://www.enel.com/en-GB/group/commercial_network/
22.
http://www.edf.com/html/RA2011/en/index.html
23.
Outage Management System in NDPL….. the first in India by Anurag Basu
24.
http://www.smartgrids.eu/
25.
http://www.smartgridnews.com/
26.
http://smartgrid.ieee.org/
27.
http://smartgrid-for-india.blogspot.com/
28.
http://www.apdrp.gov.in/
29.
http://www.pfcindia.com/
30.
http://www.ventyx.com/
31.
http://www.smartgrid.gov/
32.
http://www.ge-ip.com/products/family/proficy_hmiscada_ifix
33.
http://www.energy.siemens.com/fi/en/automation/power-transmissiondistribution/control-systems/spectrum-power.htm
34.
http://www.gillam-fei.be/scada.php
35.
http://www.survalent.com/
36.
http://www.alstom.com/grid/products-and-services/electrical-networksystems/electrical-distribution-management/
37.
http://www.iea.org/
85

Annexure
Annexure 1: Study of Investment on SCADA/EMS/DMS systems and software by world utilities by Newton Evans Market Research Company .
86

87

Annexure 2: Region wise /Country wise investment on SCADA/EMS in 2008-10
88

89