Summer Internship Report

On

“DUE- DILIGENCE OF SCADA SOLUTIONS

FOR

INDIAN POWER DISTRIBUTION UTILITIES”

UNDER THE GUIDANCE OF

Mr. K P Singh Parmar, Assistant Director, MS, NPTI

&

Mr. Ankur Jaiswal (Head Infrastructures Solutions)

Enzen Global Solutions Pvt Ltd

Submitted by

Chanmeet Singh Syal

MBA – Power Management

Roll No 1120812207, Batch 2011-13

MBA (POWER MANAGEMENT)

NATIONAL POWER TRAINING INSTITUTE

August 2012

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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 quick-

fix 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.

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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.

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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:

S.

No.

Software Package Company providing

solution

Country/Distribution

Company

1 iPower for iFix GE New Zealand/PowerNet

2 Spectrum Power Siemens Austria/ KelagNetzGmbh

3 Oasys

SCADA,DMS,OMS

Televant(Schneider electric) Rome, Italy/Enel

4 DMS Ventyx(now ABB) USA/CPS Energy

India/Reliance Infra

5 Survalent Survalent Technologies Georgia US/Flint energy

6 LYNX Gillam Fei Geneva/SIG

Metz/UEM

7 e-terra distribution Alstom Netherlands /Stedin,

Due to constraint of time we have considered only 12SCADA software packages.

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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.

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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

enterprises across the UK, India, Europe and the Middle East in regulated as well as

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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)

2.3 Need of SCADA in Indian Power Sector:

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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

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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

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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.

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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.

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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.

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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.

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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.

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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

Interface

After

sales

suppor

t

Operating

platforms

and ease of

integration

Very High

High

Average

Low

Very Low

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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.

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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.

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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.

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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 long-

term 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 Name of company

iPower with iFIX 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

• DCOM

34

• 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

Requirements

35

• 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 PowerNet in Invercargill, New Zealand

Customers 64,000

Total I/O 10,000

Servers Dual Servers in redundant automatic fail-over configuration

Clients Two control room Operator workstations, each with three monitors working as a single desktop

Three clients distributed on the corporate LAN

LAN Dual redundant LAN, LAN switch interface to corporate LAN

Software 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

On Demand Power Distribution

36

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 monopoly-

controlled 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.

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

37

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 Management

“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

Considering the above mentioned case studies and the features of the software package the

relative points

38

Rel

iabi

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Res

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Bus

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s

Exp

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Func

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Gra

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Use

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Inte

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e

Aft

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les

supp

ort

Ope

ratin

g

plat

form

s and

ease

of

inte

grat

ion

Very

High(5)

High(4)

Average(3)

Low(2)

Very

Low(1)

5.2

39

Name of SCADA software Name of company

Spectrum Power/DMS Siemens

Spectrum Power SIEMENS

Power Control System for the energy systems of the future.

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

Rel

iabi

lity

Res

pons

e

Bus

ines

s

Exp

erie

nce

Func

tiona

lity

Gra

phic

Use

r

Inte

rfac

e

Aft

er sa

les

supp

ort

Ope

ratin

g

plat

form

s and

ease

of

inte

grat

ion

Very

High(5)

High(4)

Average(3

)

Low(2)

Very

Low(1)

45

5.3.

Name of SCADA software Name of company

OASyS SCADA, DMS, Responder OMS,

ArcFM GIS 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.

47

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 —

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

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Considering the above mentioned case studies and the features of the software package the

relative points

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pons

e

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High(5)

High(4)

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Very

Low(1)

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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.

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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:

1: 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)

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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

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High(4)

Average(3

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Low(1)

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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:

Single Master Station

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Dual-redundant Master Station

Tri-redundant Master Station

Quad-redundant Master Station

VMware Master Station

Warm-standby Master Station

Smart 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 wide-

range 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.

Switching Study

Load Transfer Alternatives Study

Short-Circuit Study

Post-Fault Load Transfer Recommendations

Capacitor Dispatch Study

Reports:

Line Section Data

Load Flow Data

Load/Customer Report

Voltage, Loss and Load Balance Report

Line Section Report

Capacitor and Regulator Report

Switching Devices Report

Load Margins Report

Min/Max Voltage Report

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.”

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Considering the above mentioned case studies and the features of the software package the

relative points

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High(4)

Average(3

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Low(2)

Very

Low(1)

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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

o SEL Lausanne : import of LS 3000

65

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,

SOE,

66

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

in substations and with control centres in other geographic areas.

67

"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

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Very

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High(4)

Average(3

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Very

Low(1)

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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.

The additional applications that can be included in an e-terra distribution solution are:

69

● 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 real-

time 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

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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

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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 self-

healing, 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

Rel

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Very

High(5)

High(4)

Average(3

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Low(2)

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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 room-

based 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.

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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.

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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 ).

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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:

S.N

o.

Soft

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1 iPower for iFix 5 3 3 3 3 3 3 23

2 Spectrum Power 5 5 4 4 3 5 4 30

3 Oasys

SCADA,DMS,OMS

4 3 4 4 3 5 3 26

4 DMS by Ventyx 5 4 3 4 3 4 4 27

5 Survalent 5 4 4 4 3 4 5 29

6 LYNX 4 3 3 4 3 3 3 23

7 e-terra distribution 4 4 4 4 3 4 4 27

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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.

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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 sub-

stations 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.

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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:

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.

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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.

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.

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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.

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.

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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.

Bibliography

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OF ELECTRIC UTILITY SCADA SYSTEMS” 7803-3713-1/1997 IEEE

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2. ANSMEEE C37.1-1- 1987, IEEE standard definition specification and analysis of

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Evans, Jan 2011, Pages: 335http://www.newton-evans.com/reports/

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Standard IEC 61968-1 First Edition 2003-10

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(PFC) for SCADA/DMS implementation under RAPDRP Part A.

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studies and their impact on ERA-Net Smart Grids by Smart grid Era Net

Deliverable 4.2.1

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10” by Power Finance Corporation Limited

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16. Implementation of Accelerated Power Development and Reform Programme

Ninth Report by Ministry of Power

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distribution_automation_2012_2016_technologies

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http://en.wikipedia.org/wiki/Electricity_distribution_companies_by_country

21. http://www.enel.com/en-GB/group/commercial_network/

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distribution/control-systems/spectrum-power.htm

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37. http://www.iea.org/

Annexure

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

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

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