GURGAON - Dakshin Haryana Bijli Vitran...

DETAILED PROJECT REPORT

SMART GRID PROJECT

of

GURGAON (Sectors 1 to 57)

STAGE – I

Dakshin Haryana Bijli Vitran Nigam

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Table of Contents Table of Contents .......................................................................................................... 2

1 Executive Summary ............................................................................................. 10

1.1 Need of Smart Grid leading to Smart City ........................................................ 10

1.2 Gurgaon Smart Grid Leading to Smart City ...................................................... 11

1.3 Geographical Map of Gurgaon under Smart Grid ............................................. 12

1.4 Project Area :Sector 1 to 57 Gurgaon ............................................................... 13

1.4.1 Demographic Statistics .............................................................................. 13

1.4.2 Electricity Profile of Project:Sector 1 to 57 Gurgaon ................................. 13

1.4.3 Area to be covered under Project (Sector 1 to 57) ..................................... 15

1.4.4 Line Loss Trend of area from Sectors 1 to 57 Gurgaon(%) ....................... 16

1.4.5 Past Load growth trend of Gurgaon Sectors-1 to 57 .................................. 16

1.5 Transmission Infrastructure & Challenges ........................................................ 17

1.6 Challenges in Distribution: ................................................................................ 18

1.7 Primary Bottleneck in establishment of Smart Grid: Inadequate Electrical Infrastructure .............................................................................................................. 19

1.8 Objectives of the Project ................................................................................... 20

1.9 Proposed Strengthening of Infrastructure ......................................................... 22

1.10 Scope ............................................................................................................ 23

1.11 Estimated Cost of Project (Sector 1 to 57) .................................................... 25

1.12 Financing Strategy ........................................................................................ 26

1.13 Implementation strategy and ownership ........................................................ 27

1.14 Cost Benefit Analysis .................................................................................... 27

2 Original Approach ................................................................................................ 29

2.1 Conceptualization of Smart Grid Project Leading to Smart City ....................... 29

2.2 Strategy for the Project of Phase-I of Part-I ...................................................... 34

2.3 Action taken for the Project of Phase-I of Part-I................................................ 35

2.4 Estimated Cost of Project (Phase I)DLF City Subdivision ................................ 35

2.5 Financing of Project .......................................................................................... 37

2.6 Present status of work planned under original approach(DLF City S/Div.) ....... 38

3 New Approach ...................................................................................................... 39

3.1 Genesis of alternate approach in Smart Grid Project leading to Smart City ..... 39

3.2 Need of Alternative Approach ........................................................................... 47

3.3 Strategy for the Project as per alternate approach in various stages (I to IV) ... 48

3.3.1 Stage-I ....................................................................................................... 49

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3.3.2 Stage-II ...................................................................................................... 50

3.3.3 Stage-III ..................................................................................................... 50

3.3.4 Stage-IV ..................................................................................................... 50

3.4 Consolidated methodology of execution: .......................................................... 50

4 Project Cost Estimation ....................................................................................... 54

4.1 Cost Estimate under Original Approach (DLF City S/D ie Phase-I of Part-I) .... 54

4.1.1 Key features of Original approach .............................................................. 54

4.1.2 Estimate for DLF City Subdivision(Phase-1 of Part-1) ............................... 55

4.2 Cost Estimate under Revised Approach ........................................................... 56

4.2.1 Key features of revised approach .............................................................. 56

4.2.2 Revised estimate for Gurgaon sectors 1 to 57 ........................................... 58

4.2.3 Cost Estimate for DLF City Subdivision under revised strategy ................. 59

4.2.4 Cost Estimate for Sectors 1 to 57 Gurgaon(Excluding DLF City S/D) under revised strategy ...................................................................................................... 61

5 Transmission ........................................................................................................ 63

5.1 Analysis and Challenges in Gurgaon transmission network ............................. 63

5.2 Present No. of Substations with installed capacity in Gurgaon ......................... 63

5.3 Present Power Map of Gurgaon ....................................................................... 64

5.4 Power Supply feeding points for Gurgaon ........................................................ 64

5.5 Challenges in Gurgaon Transmission System .................................................. 65

5.6 Transmission System Studies .......................................................................... 65

5.7 Future Transmission Capacity .......................................................................... 66

5.7.1 Existing/Proposed 400/220 kV Substations to feed Gurgaon area ............ 66

5.7.2 Transformation Capacity FY 2016-17( Action Plan 2021-22) ..................... 67






5.8 Installed capacity/Maximum demand at various distribution ............................. 70

6 DISTRIBUTION ...................................................................................................... 71

6.1 Analysis of existing infrastructure and Identification of Challenges .................. 71

6.1.1 Radial electrical Network............................................................................ 71

6.1.2 Policy of Independent feeder ..................................................................... 71

6.1.3 Non-availability of Right-of-Way ................................................................. 72

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6.1.4 Multiple 11 kV Feeders on a Pole .............................................................. 72

6.1.5 Aged and poor LT distribution network ...................................................... 72

6.1.6 Manual Fault Rectification .......................................................................... 72

6.1.7 Unregulated Constructions......................................................................... 72

7 Developing the Smart Grid .................................................................................. 81

7.1 What is Smart Grid ........................................................................................... 82

7.2 Advanced Metering Infrastructure (AMI) ........................................................... 85

7.3 Peak Load Management (PLM) ........................................................................ 90

7.3.1 DR and DSM for All Consumers ................................................................ 92

7.3.2 Power Quality Improvement ....................................................................... 93

7.4 Distribution Transformer Monitoring Unit (DTMU) ............................................ 95

7.5 Smart Grid Control Centre ................................................................................ 96

8 BENEFITS OF SMART GRID INITIATIVES .......................................................... 97

8.1 Benefits of Advanced Metering Infrastructure ................................................... 97

8.1.1 Reduction in Meter Reading Cost .............................................................. 97

8.1.2 Reduction in Field and Meter Services ...................................................... 98

8.1.3 Reduction in Off Cycle Trips ...................................................................... 98

8.1.4 Reduction in Outage Field Trip .................................................................. 99

8.1.5 Reduction in Unaccounted Energy ............................................................. 99

8.1.6 Theft / Tamper Detection & Reduction ....................................................... 99

8.1.7 Faster Identification of Dead Meters ........................................................ 100

8.1.8 Improved Distribution System Savings .................................................... 100

8.1.9 Improved Distribution System Management ............................................ 100

8.1.10 Operational Efficiency Improvement ..................................................... 101

8.1.11 Reduction in Estimated Bills ................................................................. 101

8.1.12 Reduction in Customer Call Volume ..................................................... 102

8.2 Benefits of Peak Load Management ............................................................... 102

8.3 Other Benefits................................................................................................. 103

8.4 Customer engagement plan ........................................................................... 103

9 SCADA IMPLEMENTATION ............................................................................... 105

9.1 Componentsof Grid Automation ..................................................................... 105

9.2 Illustration of automated fault restoration by SCADA...................................... 105

9.3 Requirement of Software Applications with SCADA ....................................... 109

9.3.1 Distribution Management System(DMS) .................................................. 109

9.3.2 Outage Management System .................................................................. 113

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9.3.3 Applications at Smart Grid Control Centre: .............................................. 114

9.3.4 Switching Procedure Management .......................................................... 115

9.4 Benefits of Implementation of SCADA & Software Applications ..................... 116

9.4.1 Leading functionality ................................................................................ 116

9.4.2 Operation and informative presentation of the network ............................ 116

9.4.3 Dependable Operational Safety ............................................................... 117

9.4.4 Intelligent switch order management ....................................................... 118

9.4.5 Reduction in Outage duration .................................................................. 119

9.4.6 Fast and efficient reporting of operational statistics and outages ............. 120

9.5 Implementation of SCADA in project area: Architecture & BOQ ..................... 121

9.5.1 Activities to be performed in Distribution System: .................................... 122

9.5.2 Common SCADA Control centre .............................................................. 122

9.5.3 Communication Network .......................................................................... 122

9.5.4 Field Equipments ..................................................................................... 123

9.5.5 Components of SCADA Control room ...................................................... 124

10 NETWORK UPGRADATION & STRENGTHENING ......................................... 127

10.1 Proposed Network Up-gradation / Strengthening Initiatives by DHBVN ...... 127

10.1.1 Layout of Existing 11 KV Radial feeders ............................................... 129

10.1.2 Layout of proposed 11 KV Ring Main System ...................................... 130

10.2 Proposed sequence of execution of various phases under Part-I of Project 132

10.3 Existing and proposed System study for Sample area ................................ 132

10.3.1 Existing loading details of 11 kV feeders .............................................. 133

10.3.2 Load flow analysis of existing 11 kV feeder .......................................... 133

10.3.3 Ultimate Load projection of area under S.Lok Phase-1 up to Yr. 2031 . 133

10.3.4 Load flow analysis of Proposed network ............................................... 134

10.3.5 Results of load flow analysis ................................................................. 135

10.4 Load forecasting methods for Gurugram ..................................................... 135

10.4.1 Similar-day Approach ........................................................................... 136

10.4.2 Regression Methods. ............................................................................ 136

10.4.3 Time Series. ......................................................................................... 136

10.4.4 Neural Networks. .................................................................................. 136

10.4.5 Expert Systems..................................................................................... 136

10.4.6 Fuzzy Logic .......................................................................................... 137

10.4.7 Support Vector Machines ..................................................................... 137

10.5 Proposed Network Up-gradation/Strengthening Initiatives by HVPN .......... 137

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11 COST ESTIMATES & BENEFITS ..................................................................... 140

11.1 Estimated Cost of Project (Sectors 1 to 57) ................................................ 140

11.2 Benefits ....................................................................................................... 140

11.3 Cost Benefit Analysis .................................................................................. 140

11.3.1 Benefit of Implementation of AMI in sectors 1 to 57 Gurgaon ............... 140

11.3.1.1 Reduction of AT&C losses ................................................................. 141

11.3.1.2 Reduction in average cost of billing ................................................... 141

11.3.2 Peak Load Management ....................................................................... 141

11.3.3 Outage Management System ............................................................... 142

11.3.4 Benefit due to due to augmentation of undersize LT conductor ............ 144

11.4 Summary of Benefits ................................................................................... 146

12 FINANCING STRATEGY .................................................................................. 147

13 CHALLENGES & STRATEGY FOR IMPLEMENTATION ................................ 148

13.1 Major Challenges ........................................................................................ 148

13.1.1 Environmental impacts and mitigation plan .......................................... 148

13.1.2 Statutory approvals and clearances...................................................... 148

13.1.3 Training and capacity building .............................................................. 149

14 CONCLUSION ................................................................................................... 152

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Preface

India is urbanizing at an unprecedented rate. Increasing urban population

and unprecedented load on aged and insufficient infrastructure in our cities

has forced many challenges for fulfilling basic facilities like home, energy,

employment, health, mobility etc. In addition infrastructure to supply

commodities like electricity, water, gas is becoming insufficient to cater

such an inflow of population. Improved living standard of people is resulting

into high consumer aspirations and affordability. Therefore, there is a need

for development of smart grid leading to smart cities, to provide quality life

for its citizens for inclusive growth, generate employment as well as reduce

pressure of infrastructure requirement on other large cities.

Gurgaon is an industrial and financial hub of the country with one of the

highest per capita income .It is for quite some time now that the concept of

developing Gurgaon as a Smart City has been under discussion at the

highest levels in the government, State as well as the Union.

This Detailed Project Report details the evolution of the concept for

establishment of Smart grid in Gurgaon.It explains the concept of Smart

Grid, its features and benefits to various stakeholders of DHBVN located in

sectors 1 to 57 Gurgaon.

The Executive summary providing brief details of the contents has been

given at the outset of this Detailed Project Report. Thereafter, the

origination of Original concept envisaged for establishment of Smart Grid in

Gurgaon has been detailed.It explains the various key decisions taken

during key meeting held on 08thOctober 2015, followed by the strategy to

be adopted for establishment of Smart Grid, cost estimation for initial phase

of the Project, financing model and present status of work planned for

phase-1.

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As per original schedule of project execution, the project was divided into 3

Parts and Part I was scheduled to be executed in 4 phases.

Subsequentlydetailed discussions were carried out and it was felt that with

the original approach the benefits of Smart Grid can be enjoyed by all

consumers of Gurgaon only after a long period of time. It lead to change in

the strategy/approach to be adopted for roll out of the project which has

been explained in detail under new approach. Cost estimate for Phase-I of

Part-I under original approach i.e. for DLF City Subdivision, cost estimate

for Sectors 1 to 57 Gurgaon under alternate approach and cost estimate for

DLF City subdivision under alternate approach has been detailed to

understand the difference in estimated Project costing as far as both the

approaches are concerned.

Since to meet out the future load growth of Gurgaon,the increase in

transformation capacity in sync with load growth is a must, a chapter has

been devoted to present transmission infrastructure in Gurgaon, its

bottlenecks, planning of transmission utility HVPNL envisaged under action

plan 2021-22 to upgrade transmission infrastructure and augment

transformation capacity.

The DPR also presents the analysis of present distribution infrastructure in

Gurgaon and identification of the various challenges before DHBVN in

maintaining and augmenting the distribution infrastructure.

The various attributes of Smart grid which will be implemented under Smart

grid Project Gurgaon have also been detailed out along with their benefits.

The attributes to be adopted include implementation of Advanced Metering

Infrastructure, SCADA and up gradation of distribution electrical

infrastructure capable of meeting out present day and future load demands

along with latest advancements in equipments.

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Establishment of smart grid is going to benefit both DHBVN and its

stakeholders financially and qualitatively. Cost and benefit analysis of

Smart Grid project presents financial implications of implementation of the

project.

DPR concludes with funding proposals for the implementation of the

project.

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1 Executive Summary

1.1 Need of Smart Grid leading to Smart City Energy needs of the country are growing at a very rapid pace. In order to

meet increasing energy demand, amidst growing environmental concerns

as well as energy security issues, we need to increase efficiency in all value

chain viz. generation, transmission & distribution. More importantly,

efficiency needs to be increased to a point where we shall actually be using

less energy to power more establishment / businesses. Further, to be

sustainable, we must be able to produce the amount of energy we need,

without much impact on environment like through renewable and other non-

conventional resources. Consumer aspiration on quality supply, as well as

operation in open electricity market regime, integration of renewable energy

sources which are intermittent and variable in nature, are also posing new

challenges which needs to be addressed. Smart Grid offers a solution

towards above challenges. Smart Grid is a confluence of Information,

Communication, Electrical system with Digital technologies, integrating all

users to efficiently balance demand and supply over an increasing complex

network.

Cities occupy 4% or less of the world’s terrestrial surface, yet they are

home to almost half the global population, consume close to three-quarters

of the world’s natural resources, and generate three-quarters of its pollution

and wastes. The United Nations estimates that virtually all net global

population and economic growth over the next 30 years will occur in cities,

leading to a doubling of current populations. India is also not untouched

with above phenomenon. Our cities are becoming more populated

continuously as people are migrating from rural areas towards urban areas

for more facilities, better life, education and employment. India is urbanizing

at an unprecedented rate so much that estimates suggest nearly 600

million of Indians will be living in cities by 2030, up from 290 million as

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reported in the 2001 census. Increasing urban population and

unprecedented load on aged and insufficient infrastructure in our cities has

forced many challenges for fulfilling basic facilities like home, energy,

employment, health, mobility etc. In addition infrastructure to supply

commodities like electricity, water, gas is becoming insufficient to cater

such an inflow of population. Improved living standard of people is resulting

into high consumer aspirations and affordability.

Therefore, there is a need for development of smart grid leading to smart

cities, to provide quality life for its citizens for inclusive growth, generate

employment as well as reduce pressure of infrastructure requirement on

other large cities. Strengths of Smart Grid technologies can transform cities

to Smart cities which shall facilitate in increasing human productivity,

realization of inherent urban potential and lesser use of natural resources

per person, information access & processing to improve citizen services

etc.

1.2 Gurgaon Smart Grid Leading to Smart City Gurgaon is one of Delhi's four major satellite towns and is part of the

National Capital Region of Delhi. It has an area of 1253 km² and its

demography provides a gateway for access to many other important towns

of the Northern Region. Its proximity to the capital and the Indira Gandhi

International Airport has caused its urbanization to take place at a much

faster rate in recent years and has effectuated Gurgaon to become a

leading cosmopolitan city of the world. It has also become an industrial and

financial hub of the country with one of the highest per capita income

having been recorded here. The per capita consumption of electricity in

Gurgaon is around 4000 kWh per annum which is expected to increase to

up to 6400 kWh by 2022. Consumers in Gurgaon get electricity from

Dakshin Haryana BijliVitran Nigam Limited (DHBVN), one of the distribution

utilities catering to Southern part of Haryana. It is a State Government

owned company and governed by the Board of Directors of

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DHBVN appointed by the state government. Gurgaon operation circle is

one of the five operation circles under Delhi zone and is headed by an

officer of the rank of Superintending Engineer. It has three operation

divisions under its jurisdiction:

i. City Division

ii. Sub-Urban Division

iii. Manesar Division

1.3 Geographical Map of Gurgaon under Smart Grid

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1.4 Project Area :Sector 1 to 57 Gurgaon Sectors from 1 to 57 of Gurgaon are located on both sides of Delhi-Jaipur

National highway and are almost fully occupied. This part of Gurgaon is an

important residential and commercial hub and a cosmopolitan locality with

people from all parts of India living in harmony with each other.This area

being fully occupied and being the major source of revenue for DHBVN, will

be taken up to effectuate and adopt advanced smart grid technologies to

improve upon the existing sub-transmission and distribution system. Its cost

has been estimated at around Rs.1608 Cr. approximately.

1.4.1 Demographic Statistics The Demographic profile of the project area “Sector 1 to 57 Gurgaon” is as

under:

Location Area in sq km

Population (Nos.) Average literacy

rate

Population Density

(Nos./km2) Total Urban Rural

Sector-1

to 57

225

Sq. Km 605775 605775 0

About

90%

2690 person

/km2

1.4.2 Electricity Profile of Project:Sector 1 to 57 Gurgaon

Profile of Part I of Project i.e. Sector 1 to 57,Gurgaon in the year 2015-16 is

as under:

• 224363 Nos. of consumer with an overall annual energy input of

3988 MU

• The peak demand of the area is about 1250 MW

• Annual Energy billed is 3684.10 MU and estimated AT&C losses are

9.47 %

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• The area comprises only of LT and HT consumers. There

are224363Nos. of consumers. LT Consumers-222711, HT

Consumers-1652.

• Total Sanctioned load of project area - 2875 MW.

• Total DTs installed in project area - 3991 nos.(Maintained by DHBVN)

• Total installed Capacity of DTs– 676 MVA (Maintained by DHBVN)

• Total Nos. of existing 11KV Feeders – 479 nos.

• HT line length: 2060 km

• LT line length: 2530 km

• Profile of Consumers based on sanctioned load basis

Sr.

No.

Description of load No.s

1 Single phase,Load up to 5 KW 128073

2 Three phase,Load>5 KW and <=20 KW 90784

3 Three phase,LT CT operated meter, >20 KW and <=69 KW

3854

4 HT 11 KV CT operated meter, > 50 KW 1648

5 HT 66 KV CT operated meter 4

Total 224363

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1.4.3 Area to be covered under Project (Sector 1 to 57)

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1.4.4 Line Loss Trend of area from Sectors 1 to 57 Gurgaon(%)

1.4.5 Past Load growth trend of Gurgaon Sectors-1 to 57

8.12

7.7

8.04

7.66

7.4

7.5

7.6

7.7

7.8

7.9

8

8.1

8.2

2012-13 2013-14 2014-15 2015-16

Line loss (%)

9151015

1125

1250

0

200

400

600

800

1000

1200

1400

2012-13 2013-14 2014-15 2015-16

Load

in M

W

Year

Peak Load in MW

2012-13

2013-14

2014-15

2015-16

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1.5 Transmission Infrastructure & Challenges Gurgaon has witnessed exponential power demand growth in proportion to

the district's population growth rate. Peak Demand requirement has risen to

1670 MW in 2014-15, which is almost double of last 5-6 years. In order to

meet rising demand, HVPN & DHVBN have taken up a number of steps to

strengthen its Transmission and Distribution network. Presently, Gurgaon

District receives power from two (2) Nos. 400/220 kV Substations namely

Daultabad (945 MVA) & Secor-72 (630 MVA) with cumulative

transformation capacity of 1575 MVA. 400/220kV Panchgaon (1000 MVA)

substation (PGCIL) is commissioned and is being interconnected with 220

kV Panchgaon (HVPN) for dispersal of power. Part of the demand is also

served through 220kV Samaypur, 220kV Pali and 66kV BBMB, Delhi

Substations.

Seven (7) Nos. 220 kV substation [220/66 kV & 220/33 kV] viz. at

Badshahpur, Sector 52A, IMT Manesar, Daultabad, Sector-56, Sector-72 &

BBMB Delhi, with 1860 MVA [220/66 kV-1760 MVA & 220/33 kV-100 MVA]

transformation capacity is utilized to feed DHVBN downstream network in

Gurgaon.

Challenges in Transmission:

Presently Gurgaon Transmission network faces challenges like inadequate

redundancy of 220 kV lines as well as transformers (both Power

transformers as well as Distribution transformer). These 220 kV

transmission lines and power transformers get critically loaded especially

during contingency conditions and peak summer.

Gurgaon district witnessed about 1100 MW peak demand in 2012-13,

whereas it increased to 1250 MW & 1400 MW in 2013-14 & 2014-15

respectively, which is about 12-13% annualized growth rate. Substantial

demand growth has already taken place. Therefore, demand growth at

such a rapid pace may not sustain in future and may get moderated to

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around 10% per annum in coming years. However, while carrying out

demand growth analysis, demand met through DG (10%) as well as DLF

Gas plant (104 MW), for year 2014-15 has been considered. Analysis

reveals that, peak demand requirement shall increase to about 2900 MW

by 2022. To assure 24x7 quality power supply to the model Gurgaon Smart

Grid leading to Smart City, Transmission and Distribution needs to be

strengthened to meet such massive demand requirements. Based on inputs

like demand data (node wise), information about existing and planned

transmission system, network topology etc., studies have been carried out

jointly by HVPN/DHVBN. Transmission system of various regions including

STU networks (220kV and above) available in the study time frame has

been simulated based on the data available with POWERGRID. Based on

studies, Transmission system strengthening (Zones wise) was evolved

which broadly includes following:

• Establishment of new 220kV substation (GIS) to cater to demand growth

as well as to meet requirement of new demand centers

• 220kV Multi circuit Transmission line (High capacity conductor)

(Overhead/Cables)

• Formation of 220kV Transmission ring underlying planned 400kV ring

• Augmentation of Transformation capacity on existing / under

construction / HVPN planned Substations at 220/66 kV & 220/33 kV

level

1.6 Challenges in Distribution: Based on the existing infrastructure constraints, following issues and

challenges have been identified in distribution system of Gurgaon::

• Radial distribution feeders

• Infrastructure Capacity inadequacy

• No redundancy at any level

• Overloading of transformers (around 88% transformer are overloaded)

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• Inadequate reactive compensation (about 20% of the total installed

capacity)

• Absence of SCADA & Automation

• Poor voltage regulation in distribution feeders

• High feeder losses

• Poor power quality situation

• High outage rate at 11kV feeder level

• All the expenditure to create infrastructure for ensuring 24x7 supply

cannot be made through Capex approved for 2016-17 by HERC

1.7 Primary Bottleneck in establishment of Smart Grid: Inadequate Electrical Infrastructure

It is the up-gradation of distribution system which is the major area of

concern. Not only that the existing system is badly overstretched and

overloaded, there are no right-of-ways available from where the bifurcation

can be planned. There are a number of inadequacies in existing electrical

infrastructure which makes it unsuitable to adopt Smart Grid initiatives like

automated control through SCADA, AMI implementation, roof top SPVs

integration etc. Some of inadequacies which need to be addressed before

introduction of Smart grid initiatives are as follow:

• Most of the feeders are running Over head, multiple circuits per pole

due to non-availability of right of way. Conversion of existing

Overhead network to underground network is first requirement of this

project to make feeders fault free, reduce down-time of feeders,

address existing and future problem of right of way in rapidly

urbanising Gurgaon town and to make the electrical network robust

for adoption of smart grid features.

• Air-break switches(GO switches) get damaged frequently due to

weathering, have less useful life, are not reliable and are unsafe for

operation of higher DT capacity. Replacement of Air-break switches

(GO switches) with RMUs is second requirement of electrical infra. to

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ensure automatic isolation of faulty sections, safety of network and

quick response to SCADA

• Snapping of 11 kV conductor is a normal occurance. Conversion of

overhead network to underground network will avoid such scenario

• Radial feeders which disallow back feeding of a faulty feeder due to

absence of ring main system of feeders

• Insufficient redundancy at 11 KV level which is required to be

enhanced to 100% for successful operation of 11 KV Ring Main

System.

• All the above contribute to make the whole distribution system so

vulnerable to breakdowns and tripping that the consumers’ dream of

getting uninterrupted power supply with smart features has remained

a dream. There are cities in India where breakdowns and tripping are

almost nil, transformer damage rate is almost zero and there is

almost a 100% redundancy at distribution level. In most of the best

distribution utilities in India, Underground network in Urban areas has

already been proven a success over overhead network enabling

these utilities to successfully introduce concepts of SCADA and other

features of Smart Grid.

Therefore, there is a need for development of smart grid leading to smart

city, to provide quality life for its citizens for inclusive growth, generate

employment as well as reduce pressure of infrastructure requirement on

other large cities. Strengths of Smart Grid technologies can transform cities

to Smart cities which shall facilitate in increasing human productivity,

realization of inherent urban potential and lesser use of natural resources

per person, information access & processing to improve citizen services

etc.

1.8 Objectives of the Project Main objective of this report is to analyze present system and adoption of

Smart Grid technologies and distribution network up-gradation /

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strengthening measures that will improve the performance of distribution

system of sectors from 1 to 57 in Gurgaon and will ensure 24×7 reliable

power supply to the consumers. Efficacy of these advanced

technologies of the modern era will empower consumers to participate in

energy management process and shall make distribution system more

efficient. With these aspects in view, following objectives have been

outlined for development of Smart Grid in sectors from 1 to 57 of Gurgaon

to:

• Ensure 24x7 power supply to all the consumers

• To make Gurgaon city DG Set free

• Increase in billed energy and reduction in AT & C losses.

• Improvement in reliability by reduction in outage rate and duration

• Improved administration decision making through GIS tools

• Increase in customer satisfaction and consumer awareness

• Propose Smart Grid technologies, which would facilitate efficient,

accurate & effective online recording & monitoring of the energy

exchanges in distribution system to reduce AT&C losses and

operational errors viz. reading error, bias error, typographical errors

etc. caused by involvement of human element

• Actuate empowerment of consumers to participate in the energy

management process

• Implement technologies that will enhance quality of power at doorstep

of consumers and will help in proper monitoring of assets for

extended life

• Efficient system operation by better load management

• Enable high level of customer satisfaction and increased awareness

Augmentation of existing distribution system and improvement of

commercial performance is a continuous process, requiring periodic

reviews based on the target achieved. Accordingly, present report covering

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complete details of the area in terms of existing assets, present technical

and commercial performance, IT solutions, smart grid technology

deployment; would serve as a base report for implementation of Smart grid

Project. The distribution system of project area shall be shaped like a model

Smart Grid by implementation of Smart Grid Technologies like Advanced

Metering Infrastructure (AMI), Peak Load Management (PLM), Power

Quality Management (PQM), and State-of-the-Art communication system

atop existing infrastructure.

1.9 Proposed Strengthening of Infrastructure To mitigate above challenges and to achieve the objectives, following

measures and applications are proposed as under:

• New 220/66/11 kV and 66/11 kV substations (GIS) for transfer of load

from existing overloaded substations

• Augmentation of existing 66/11 kV substation

• Conversion of 11 kV overhead system to underground cable.

• Formation of 11 kV ring main by installing RMU (Ring Main Units)

• SCADA (Supervisory Control and Data Acquisition) and OMS

(Outage Management System).

• Optic Fibre Cable up to Ring Main Units for bidirectional

communication

• Advanced metering system covering 3.5 lacs consumer till 2022.

• Load management at consumer level through Demand response and

Demand side management.

• Payment linked load shedding

• Integration of proposed system with R-APDRP

• Regulatory mechanism for Time of day tariff for all category of

Consumers, tariff rationalization and mandatory energy efficiency

measures compliances

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• The complete ownership for operation and maintenance will be with

DHBVN and HVPN, as the case may be, even in builder area after

the installation and commissioning of the new system.

1.10 Scope Broadly, the scope of work under the proposed project covers the following:

a. HT line: Bifurcation of overloaded 11 kV feeders having load more

than 150 Amps. The load projection upto 2031 to be taken into

account. The existing overhead 11 kV lines network shall be

converted into underground cable network using 11 kV XLPE cables.

The provision of overhead lines with ACSR/ cable shall be kept

sparingly.

b. LT line: Bifurcation/ Augmentation of LT line with ACSR conductor/

cable and additional new LT line on need basis as per site

requirement and provision of additional poles in the existing LT Line

to reduce the span length. Provision of LT AB Cable or LT

Underground XLPE cable, primarily in village areas falling within the

urban area sectors 1-57 and the theft prone areas, shall be made as

per need basis.

c. Ring Main Units (RMUs): The Ring Main Units shall be provided at

HT line T-off, HT connection as sectionalisers, providing ring

configuration for alternate backup supply. The RMUs to be installed

under the project shall be motorized with FPI but without FRTU and

which shall have the SCADA capability for connecting FRTU in future

for enabling the SCADA functionality up to the DT level.

d. Distribution Transformer: Considering the future load growth

additional distribution transformers as well as Augmentation of

overloaded distribution transformers shall be proposed. The loading

on the DTs shall be limited upto70% of rated capacity.

24

e. LT panels/ protection: Provision of the LT/ACB or LT/MCCB on the

outgoing side of the 400KVA and above capacity DTs shall be made.

For below capacity DTs conventional erection standards to be

followed.

f. Load clubbing: All the HT connections running on under loaded

independent feeders on same route may be shifted/clubbed on one

feeder with the provision of ring main unit and redundancy within the

ambit of HERC regulations and adequately addressing the open

access issue.

g. SCADA implementation: SCADA to be implemented only up to the

substation level in one go for whole Gurgaon for which consultant

shall be appointed. However, the provision of SCADA being capable

of serving till the DT level shall be retained. Therefore, the optical

fibre cable shall be laid underground alongside 11 kV HT cables

simultaneously while laying the HT line underground.After laying of

underground 11 kV infrastructure in stage-I,SCADA will be

implemented upto DT level by simultaneously installing FRTUs in

RMUs.

h. AMI implementation: The work of AMI shall also be implemented in

one go for whole Gurgaon under stage-III for which consultant shall

be appointed.

i. Project Area phasing: For the implementation of provisions under

the new approach, the Sectors 1 to 57 shall be divided into 8 different

smaller zones starting with critical areas and further extended to other

areas out of sector 1 to 57. The NIT cost of each phase will be

ranging between125 to 200 Cr.

j. Assumptions:

1. While deriving the BOQ some assumptions have to be made

which are required owing to the likely hindrances to be faced

while execution of the project such as the quantity of cable

25

laying through open digging and through trenchless digging.

The ratio has been assumed as 60% to 40% respectively.

2. Similarly, length of different types of road i.e.interlocking tiles

road,CC road,Metallic(Bituminous) road and brick on edge road

which will be dug and restored for laying of underground cables

has been assumed as 3,7,7 and 3 % respectively of total circuit

length for manual digging.

1.11 Estimated Cost of Project (Sector 1 to 57) Sr.No. Description /Major head of

items Unit Unit Rate

(In lacs) Sector 1 to 57

Total Qty. Amt (In Lacs)

DISTRIBUTION SYSTEM

1 HT U/G Cables (Various Sizes) KM 19.75 2820 55705.5

2 LT UG cables (Various sizes) KM 3.39 300 1017

3 LT Feeder Pillar No.s 1.77 1500 2659.03

4 RMU(Ring Main Units) * No.s 7.80 3000 23404.05

5 Distribution T/F(11/.433kV) No.s 8.89 1676 14899.64

6 Optical Fiber and PLB-HDPE Pipe KM 1.30 2820 3664.58

7 Street Light No.s 0.40 0 0

8 ACSR conductor/LT AB cable KM 0.65 10120 6578

9 Civil work for foundation of DT/RMU/FP etc

No.s 0.14 6176 875.56

10 Civil work for underground laying of cable/optical fiber

Mtr. 3.42 2820 9634.77

11 Fencing R/ Mtr 0.04 46760 1942.87

12 RCC slabs and route markers No.s 0.002 3290000 8005.29

13 Cost of road cutting/restoration Sq.mt. 684.85 182592 1248.9

14 Cost of other minor items/works L/S 1284.1

Sub-Total(in Rs Lacs) 130950

SCADA& OMS

15 SCADA & OMS along with civil work required for the project

Lot 7029

AMI(including DTMU)

26

16 Field Equipment for AMI & PLM Lot 14226

17 IT System and Integration for AMI & PLM

Lot 1326

18 Field equipment for PQM & DTMU Lot 3840

19 Consumer Education and Awareness Lot 100

Sub - total 19691

Total DHBVN A 1576.7

TRANSMISSION-HVPN

20 Substations & Lines 0

TOTAL (HVPN) - B 0

Total Consultancies Charges – C (2% of (A+B)) 3153

GRAND TOTAL (A+B+C)(In Lacs) 160823

GRAND TOTAL (In Crores) 1608

*Cost of RMU includes cost of motorized RMU with FPI & FRTUs

1.12 Financing Strategy

For making an estimated expenditure of Rs. 1608 crores, the funding

mechanism proposed is as under:

1. The scheme comes under 5.1(d) of the guidelines for disbursement of

funds under Power System development Fund (PSDF).Out of estimated

cost of 1608crores, components of 1093.40 crores are eligible for

Disbursement of funds for renovation and modernisation to remove

congestion under PSDF(Power system development scheme) for

sanction of 75% amount of eligible components. 75% amount of cost of

eligible components comes to be =0.75X1093.40= 820crores

2. Expenditure is proposed to be made in two (2) years i.e. 2017-18 and

2018-19 expectedly in the ratio of 30:70 percent respectively.

3. The balance Rs. 788crores is proposed to be arranged/met

throughCAPEX of DHBVN by taking loan from funding agencies. It is

shown in tabulated form as under:

It is shown in tabulated form as under:

27

Arrangement of Funds

1st Year (2017-18)

2nd Year (2018-19)

Total (in crores)

Grant from MoP (GoI)

246 574 820

Loan from funding agencies

236 552 788

TOTAL 482 1126 1608

1.13 Implementation strategy and ownership The work shall be awarded through open tendering on the basis of per unit

cost of each item and shall be awarded to the firm who quotes the lowest

premium. The turnkey contractor will carry out the detailed survey in the

field before execution of work. The work shall be awarded on “Concept to

Commissioning”basis. The ownership of the new system after

commissioning will be that of DHBVN.

The work shall be executed in phased manner without disturbing the

existing distribution/transmission system. After laying of new system the

connectivity of the newly laid system with old system shall be done in a

phased and planned manner so that the supply to the consumers is

minimally affected.11 kV Underground cable will be laid first between

various load centres to be connected to a particular 11 kV feeder. This will

be followed by shifting of load of HT Connections/DTs, which are to be fed

by another feeder as per integrated planning, to another existing feeder.

After shifting of load, 11 kV underground feeder and various U/G cable

portions will be energised in a sequential manner.Other associated LT

improvement works shall be carried out in parallel/after completion of 11 kV

work in a pocket.

1.14 Cost Benefit Analysis Expected benefits per year in year 2020 from above mentioned smart grid

initiatives are summarized in table below:

Sr. no.

Initiative Benefits (in Rs. Cr. Per year)

28

1 Advanced Metering Infrastructure (AMI) 87.60

2 Peak Load Management(PLM) 22.94

3 Outage Management System (OMS) 7.95

4 Benefit due to augmentation of LT conductor

52.27

Total 170.76

29

2 Original Approach

2.1 Conceptualization of Smart Grid Project Leading to Smart City

Gurgaon is one of Delhi's four major satellite towns and is part of the

National Capital Region of Delhi. It has an area of 1253 km² and its

demography provides a gateway for access to many other important towns

of the Northern Region. Its proximity to the capital and the Indira Gandhi

International Airport has caused its urbanization to take place at a much

faster rate in recent years and has effectuated Gurgaon to become a

leading cosmopolitan city of the world. It has also become an industrial and

financial hub of the country with one of the highest per capita income

having been recorded here. The per capita consumption of electricity in

Gurgaon is around 4000 kWh per annum which is expected to increase to

up to 6400 kWh by 2022. Consumers in Gurgaon get electricity from

Dakshin Haryana BijliVitran Nigam Limited (DHBVN), one of the distribution

utilities catering to Southern part of Haryana. It is a State Government

owned company and governed by the Board of Directors of DHBVN

appointed by the state government. Gurgaon operation circle is one of the

five operation circles under Delhi zone and is headed by an officer of the

rank of Superintending Engineer. It has three operation divisions under its

jurisdiction:

i. City Division

ii. Sub-Urban Division

iii. Manesar Division

It is for quite some time now that the concept of developing Gurgaon as

a Smart City has been under discussion at the highest levels in the

government, State as well as the Union. On 29th April 2015, Hon’ble

Union Minister of State (Independent Charge) for Power, Coal and New

& Renewable Energy co-chaired a meeting with the Hon’ble Chief

30

Minister Haryana at the headquarters of Power Grid Corporation of india

Ltd. (PGCIL) Gurgaon wherein it was decided to take all necessary

steps to improve power situation in Gurgaon primarily with the two

objectives in mind to start with. One, to provide 24x7 uninterrupted

electricity to all the consumers and two, to make Gurgaon Diesel

Generator free town in a year and to scale up the infrastructure further to

make it a Smart Grid. Among the various subjects discussed during the

meeting, the following three were thought of as the priorities:

i) Strengthening / Up-gradation / Modernization of Power Transmission,

Sub-transmission & Distribution infrastructure to assure 24x7

uninterrupted Power Supply to all the categories of consumers and to

make Gurgaon Diesel Generator Set Free within next one year

ii) Map Gurgaon through Geographical Information System (GIS)

technology

iii) Smart Traffic & Surveillance Management.

PGCIL CMD Mr. Naik made a presentation on that day suggesting

making Gurgaon the first smart city of India especially with regard to

Power, Water Supply, Sewage, Roads and Traffic.

PGCIL collected the data from DHBVN Gurgaon Circle and prepared a

draft DPR for up-gradation of the Power System in which they suggested

complete substitution of the present day overhead system with the

underground system by laying cables, providing 100% redundancy at

transmission as well as distribution level, providing SCADA, providing

Advanced Metering Infrastructure (AMI) and all other IT initiatives to

reduce human interface and create an infrastructure to match with the

best in the world

The cost PGCIL anticipated initially was INR 9500 crores (around 7000

crores for Distribution and 2500 crores for transmission), which was

subsequently scaled up to around 12000 crores (around 7500 crores for

distribution and 4500 crores for transmission).

31

PGCIL made a presentation before the Hon’ble CM Haryana on 9th

June 2015 and suggested that given the go-ahead, PGCIL would be

able to accomplish the project for whole of Gurgaon in less than 2 years.

Hon’ble CM Haryana expressed his concern over the huge investment

involved and scarcity of funds with the government. Hon’ble CM

Haryana also expressed his concern as to how the whole investment

would be recovered.

CMD PGCIL apprised the house that recovery could be done by levying

reliability surcharge from the beneficiary consumers for a period of

around 25 - 30 years.

Again on 8th October 2015, the discussions on smart grid continued and

a meeting was held at Shram Shakti Bhawan, New Delhi. It was co-

chaired by Hon’ble Chief Minister Haryana and the Hon’bleMoS (IC)

Power, Coal and Renewable Energy Departments, Government of India

wherein issue of setting up smart grid in Gurgaon was discussed at

length and to make it an iconic city for rest of the country to follow.

Presentations by PGCIL and Power Department Haryana were made

during the meeting.

After the detailed discussions, following decisions were taken, so far as

Smart Grid Project of Gurgaon is concerned.

1. The Smart Grid Project may be taken up only in respect of Sectors 1

to 57, Gurgaon in the first phase. As the development in Sector 58 to

115 is likely to take place over a long period of time and there are no

issues of distribution in Manesar area, it was agreed not to make it

part of the project for the time being.

2. It was discussed that the project of setting up of Smart Grid including

SCADA and Smart Metering(AMI) in entire area of 1 to 57 Sectors will

cost approximately Rs. 7000 crores.

3. HVPN and DHBVN will take steps immediately for establishing

SCADA in whole of Gurgaon at the first phase itself. A detailed action

32

plan in this regard will be submitted by MDs of HVPN and DHBVN on

priority.

4. It was observed that the area under DLF Sub-Division falling on the

left side of Delhi- Jaipur Highway (NH-8) within the area of Sectors 1

to 57 has a load demand of 250 MW. If the load of Cyber City and

certain other areas around DLF which are presently being served by

diesel generating sets is taken into account, the load will come to

about 500 MW. This area is most disturbed and facing maximum

problem because the system constraints and overloading. Also, there

are serious problem of availability of right of way available for further

extension/addition of the system.

It was decided that area under DLF Sub-Division be taken up for

inclusion under the Smart Grid Project. Necessary steps should be

taken to prepare DPR & float NIT for this area within 30 days.

5. It was estimated that the Smart Grid Project in DLF Sub-Division area

will cost about Rs. 1200 crores. It was decided by Union Minister

Govt. of India that 25% grant for the project will be given out of Power

System Development Fund (PSDF) and balance 75% of the project

cost will be given as loan by power finance corporation (PFC) on soft

terms.

6. The suggestion given by committee of engineers that the entire

distribution system in this area may be converted to 33KV level and

the entire 33KV as well as the LT system to be laid preferably

underground were accepted.

7. It was discussed that part of LD system in the area belongs to

builders/developers which will have to be laid at their cost as they

may not come forward to bear the cost of new system. It was decided

that since smart city project of Gurgaon is being developed as a part

of GOI plan on smart cities, GOH (DHBVN & HVPN) may go ahead

33

with replacing their LD system as part of the project. However, the

dismantled equipment will become property of DHBVN & HVPN.

8. By conversion to 220/33KV GIS system, it is likely that some land

under 220/66 KV Sub-Stations may get release. An estimate of such

lands which may become available should be made and same could

be monetized for funding this as well as other projects of Smart Grid

in Gurgaon.

9. A designated group comprising of a Chief Engineer, two SEs, four

XENs and sufficient number of SDOs and other related staff should

be constituted immediately with the approval of Govt. of Haryana

which will exclusively deal with the Smart Grid Project in Gurgaon.

The necessary action for constitution of a dedicated group will be

taken by DHBVN.

10. In the entire area of Smart Grid, 100% metering should be “Smart

Metering”.

11. It was observed that DHBVN has filed a Petition before HERC for

levy of Reliability Surcharge on the consumers whose power supply

will be covered under this project. Decision by the HERC in this

regard should be expedited.

12. Since it is a vast project and involves maximum investment, approval

of Council of Minister of Haryana may also be obtained for its

execution.

13. PSCM, Haryana has also issued the summary record of discussions

held on 8th October 2015 during the meeting held by Hon’ble CM

Haryana with the Minister of State (IC) for Power and Coal) at Shram

Shakti Bhawan, New Delhi for the Smart Grid City Gurgaon. The

additional decisions taken, besides the ones listed above in points “1

to 12” are reproduced as under:

i) To be implemented in Sectors 1-57 primarily – Central purchasing

of Cables, Meters and Transformers

34

ii) Specifications of transmission set up to be vetted by the Central

Committee

iii) Specifications of sub-contractors to be revised

iv) Spare an IAS officer for implementation of the project

(Copy of the Minutes of meeting dated 8th October and copy of

summary of record issued by the PSCM, Haryana are annexed

at Annexure A for reference.)

2.2 Strategy for the Project of Phase-I of Part-I a) To cater the present as well as future load growths, 6nos. 66/11kV

Sub-station would be constructed at the load centers.

b) Switch over from overhead HT and LT system to underground system

by laying cables through trenchless boring or otherwise by simple

digging, as the case may be. Where the laying of underground cables

will not be possible, an overhead system on mono-poles will be

erected.

c) All the new system will be planned with load projections up to 2030-

31

d) 100% redundancy level will be created at the distribution level

whereas N-1 level redundancy will be created at the transmission

level and substations.

e) Remote Terminal Units (RTUs) and Ring Main Units (RMUs) will be

installed on different sections to ensure uninterrupted power supply

f) Supervisory Control and Data Acquisition (SCADA) system for total

area of Gurgaon and Advanced Metering Infrastructure (AMI) on

selected high end consumers will be implemented

g) Following software applications will be implemented and integrated

with SCADA and AMI:

• OMS - Outage management system.

• PMS – Peak Load Management System.

35

• DMS – Distribution Management System

• Distributed Generation.

h) Communication will be through Optic Fiber Cables

i) Post Commissioning O&M of the new system for 5 years will be in the

scope of the agency who executes the project and the SLAs will be

signed in that regard

2.3 Action taken for the Project of Phase-I of Part-I Being first of its kind of the project in the country, it was proposed that

the project may be implemented only for Phase-I of part-I, as the area

pertaining to DLF Sub-Division was considered to be the easiest to

tackle with due to least congestion and smallest in area with involvement

of less expenditure. Also people in this area are good payers but have

not been able to get quality supply.

Out of 7000 crores anticipated against Part I, Rs. 1382.36crores was

estimated against Phase I of Part-I.

The distribution company DHBVN took up thedistribution work and the

transmission company HVPN took up the transmission work. PGCIL was

appointed as a consultant for the project.

2.4 Estimated Cost of Project (Phase I)DLF City Subdivision

Sr.No. Description/Major head of items

Unit Quantity Total Supply Cost

Erection Total (In Lacs)

In Lacs

1 HT Cables(Various Sizes)

KM 281.42 5338.45 232.11 5570.55

2 LT UG Line (Various sizes)

KM 1923.07 6248.14 271.69 6519.83

3 LT Feeder Pillar No.s 7451 13208.31 229.70 13438.02

4 RMU(Ring Main Units) with FRTU &FPI

No.s 563 4317.08 750.07 4392.16

36

5 Distribution T/F(11KV/.433KV)

No.s 240 2486.44 43.24 2529.69

6 Optical Fiber and PLB-HDPE Pipe

KM 259 322.54 14.02 336.57

7 Street Light No.s 11000 4395.35


No.s 8394 1189.96 1189.96


Mtr. 1043000 3563.50 3563.50

10 Fencing R/ Mtr 9711 371.21 32.27 403.49

11 RCC slabs and route markers

No.s 905430 2165.45 37.66 2203.11

12 PSS No.s 15 471.47 8.19 479.67

13 Cost of other minor items/works

L/S 1139.81 128.1 1267.91

14 5 years O & M @10% 4152.73

Sub-Total 50442.32

SCADA & OMS/DMS 1 SCADA & OMS along

with civil work required for the project

lot 10055

AMI (Including DTMU)

1 Field Equipment for AMI & PLM

lot 3409


lot 672

3 Field equipment for PQM & DTMU

lot 756

4 Consumer Education and Awareness

lot 10

Sub-Total 4847

TOTAL DHBVN-A 65344.32

TRANSMISSION-HVPN 1 Substations & Lines lot 70182

TOTAL (HVPN)-B 70182 Total Consultancies Charges-C(2 % of (A+B)) 2710.52 GRAND TOTAL (A+B+C) 138236.8

37

Remarks:Consumer education and awareness cost of Rs 10 lacs under AMI has been taken as cost of campaigns required to be carried out in print/electronic media for sensitizing consumers about various features of AMI like Demand response, Time of day tariff etc.

2.5 Financing of Project The combined DPRfor Phase-I DPR of Rs. 1382.36 Crore for

Distribution (DHBVN) & Transmission (HVPN) work was prepared for

Phase-I of the project i.e. for DLF Sub-Division and got vetted from

PGCIL and submitted to MOP for sanction of the 25% grant from PSDF.

Ministry of Power, Government of India has sanctioned the grant of Rs.

273.20 Crores from PSDF towards renovation and Modernization of

distribution system of DHBVN, Haryana vide letter dated 05.11.2016

with certain terms and conditions for implementation of the aforesaid

scheme.

For the balance 75% of the project cost, the matter was taken up with

Power Finance Corporation (PFC) for loan on soft terms which is to be

recovered through reliability surcharge over and above the normal tariff

structure from the project area consumers. PFC, GOI also accorded ‘in

principal’ approval for the loan of 60% of amount of project cost vide

their letter no.03/22/DHBVNL/Smart Grid/039311 dated 8.6.2016 subject

to DHBVN receiving the Power System Development Funds grant for

around 25% of the project cost and Government of Haryana

Commitment for 15% of the project cost on equity contribution.

Accordingly, the matter for providing 15% of the project cost on equity

contribution by the Government of Haryana has been submitted through

Cabinet note for the approval of smart grid project, Gurgaon.

A petition had also been filed before the HERC for in principle approval

of taking up the smart Grid project in Gurgaon and further approval for

levying reliability surcharge from the consumers benefitted from the

project which was admitted on 29.1.2016.

38

2.6 Present status of work planned under original approach(DLF City S/Div.)

DHBVN floated the NIT for Phase I amounting to Rs. 504.42crores (for distribution work only) during the month of April 2016. However, due to strategic change in the original approach, the floatedNIT has been dropped.

39

3 New Approach 3.1 Genesis of alternate approach in Smart Grid Project

leading to Smart City A meeting was held on 25.07.2016 at Panchkula wherein the Ld. ACS

(Power), GOI, Haryana called upon the house to express their views

on the approach and strategy adopted so far and as to whether a

better approach could be devised to come up to the expectations of

the Government for achieving following objectives at lesser cost and

fast pace.

(i) Making Gurgaon DG Set free.

(ii) Relieve residents of Gurgaon from frequent interruption in the

supply of power.

(iii) Making repair and maintenance of the system more efficient

and reliable.

(iv) Releasing connections to residents of vast areas developed by

colonizers which at present are without electricity.

(v) To strengthen the transmission system in such a manner that

sufficient redundancy is created.

(vi) To install smart metering; introduction of latest technologies for

system control and management in the form of SCADA; and to

provide for redundancy at the distribution level.

An alternative approach for implementing the Smart Grid Project was

discussed and agreed as follows:-

i) Up-gradation of the electrical system should take-place

simultaneously in whole of the Gurgaon rather than in small

geographical areas for facilitating seamless planning and avoiding

interface problems of different technologies.

40

ii) Transmission bottlenecks are one of the major problems. Against a

peak demand of 1500 MW, the transmission capacity of about

2200 MW is available at present. This should be upgraded to the

level of 5000 MW in next two to three years. M.D. HVPN stated

that bids in respect of creation / augmentation of number of

substations have already been invited and for the remaining

substations, bids will be invited during next one month. HVPNL will

deliver 5000 MW capacity within next two to three years.

iii) All the decisions taken in the meetings chaired by Hon’ble Minister

of State (IC) Power, Government of India and Hon’ble Chief

Minister, Haryana should be implemented in a time bound manner

within one year. With its implementation the problems being faced

by more than 90% of the population will be solved including

making Gurgaon DG Set free. If however, earlier approach is

continued, problems of only 5-10% population will be solved in

next two years and may take many more years for rest of the

population to get relief. This may in fact create resentment

amongst the public. Proposed implementation may pose many

unforeseen problems also.

iv) SCADA and system automation are very high technology intensive

interventions. Appropriate technology for this purpose should be

selected with utmost care and caution and under proper guidance

of experts. It is not possible to install SCADA and automation in

phases. It has to be done for whole of the Gurgaon together. In the

earlier approach, it may be very difficult to implement the solution

for whole of the Gurgaon.

The alternative approach for this should be that a consultant

should be appointed for preparing a project report for implementing

SCADA in whole of Gurgaon in one go. Further action in this

41

regard for whole of Gurgaon together should be taken in

accordance with the advice of the consultant.

v) One of the important components of the Smart Grid is installation

of smart meters. It was observed that three different meter reading

technologies are already being used in the city namely, Automatic

Metering Reading (AMR) in respect of HT consumers above 50

kW; Data downloading through Common Meter Reading

Instrument (CMRI) in respect of load 20-50 KW and the Manual

Reading in respect of rest of the consumers.

Government of India, Ministry of Power is in the process of

determining the specifications of “Smart meters””. The installation of

Smart meters pre-supposes design of proper Smart metering

Software and installation of complete backend system. Another

important factor is reliable communication system. Multiple options

are available for communication system as well. Much more

expectedly, present organizational structure and manpower culture

must also change for operation of the new technology.

It was observed that it would not be advisable to install such a system

in a piecemeal manner in different geographical areas of the city. The

system has to be selected for entire geographical area even though

different categories of the consumers could be brought on to it in

phases. It was further observed that World Bank has sanctioned an

Advanced Metering Infrastructure (AMI) project for Gurgaon involving

a cost of about Rs.150 crores. This project report and tendering

process stands approved by the World Bank. Efforts will have to be

made for integrating this system into Smart Grid Project. It was

unanimously opined that this should also be implemented in the entire

42

geographical area by adopting the new / alternative approach to the

Smart Grid Project. It may not be possible in the earlier approach.

During the meeting the advantages of the new alternative approach

were highlighted which are as follows:-

(i) It will involve much lesser cost. In fact almost all the problems of

residents of Gurgaon in respect of getting un-interrupted power

supply can be solved within 1-2 years at a cost of only Rs.300-400

crores by the DHBVNL and Rs 300-400 crores by the HVPNL. It

will also make the city DG set free.

(ii) In the earlier approach it can take several years time whereas in

the new approach the entire population will get relief immediately.

Further, it is almost certain that all the anticipated results would be

achieved in the alternative approach because of usage of tried and

tested technologies with which all the officers and functionaries are

fully familiar. As against this in the earlier approach the time

involved may be many years; the outcomes are uncertain because

of its being a unique project of its kind in the country; and the

manpower being not fully trained in operating the new system.

(iii) Under the new approach there will be no need for raising tariff of

industry and other consumers. The entire expenditure can be

made out of the CAPEX permitted by the HERC and the funds

sanctioned by the Central Government.

It was decided that a proposal may be submitted to the State

Government for permitting the implementation of Smart Grid Project

in Gurgaon through the alternative approach. After approval of the

Hon’ble C.M., Haryana , the Ministry of Power, Government of India

will also be apprised of the same. In this regard, it was desired by the

Honb’le CM, Haryana that how the implementation of smart Grid

43

Project in Gurgaon through the proposed alternative project is

different from the decisions taken during the meeting under the

chairmanship of Union minister of State (IC).Accordingly the

drawbacks of the original approach were submitted as follows:

a) The phase I of Smart Grid Project would cover only 10% of the

population of present day Gurgaon i.e. Sectors 1 to 57.

b) There are so many other utilities’ services running underground of

which we do not have the route maps or other relevant details.

Under such circumstances, it would be extremely difficult and may

not be possible to substitute the existing overhead network

completely with underground cables and equipment.

c) Right-of-way for erecting more nos. of 11 kV overhead feeders

has become a severe problem in Gurgaon and to find a path under

the ground would be even more difficult.

d) The anticipated expenditure as on date of Rs. 7000 crores would

most likely double by the time the works get executed.

e) In phase I also, even though the estimated cost arrived at for the

distribution works is Rs. 460 crores in the DPR, but the bids are

likely to be received with 30% to 40% premium and we may end

up at a cost of somewhere around Rs. 650 crores.

f) Since the NITs for different phases shall be floated separately,

there would most likely be different companies in different phases

which may result in problems of compatibility and inter-

dependability.

g) The kinds of services and facilities which the residents of phase I

would start availing after completion of the work in their area would

become available to the consumers of other phases after a gap of

several years. This would not only lead to differential standards of

services in different areas of the same city but would also invite

criticism and law and order problems.

44

h) Since the system uptime is already more than 23 hours per day,

there would be marginal increase in the sale of power on account

of reduction of outages and therefore hardly any noticeable

increase in the revenue to justify the kind of investment we plan to

make.

i) As most of the Capex will be utilized for providing 100%

redundancies and remote operation of equipment at distribution

level without any appreciable increase in revenue, the project

cannot support itself on the basis of return on investment. The only

way to get the money back would be by way of levying reliability

surcharge of around Re. 1 on the beneficiary consumers for the

next 20 years or so which will lead to differential tariff in the same

city again inviting criticism.

j) In the BijliSammelan held at Gurgaon in July 2016, wherein the

idea of levy of reliability surcharge was aired among the public,

there were lot of noises made against the idea and the people

present in the sammelan put up a lot of opposition to the levying of

any such kind of surcharge

k) Apart from resistance from the public, the regulator may also not

allow us to have a differential tariff within the same city. People

may even resort to go in for litigations against any such move.

l) Since the requirement of finances is huge, it is quite possible that

the project may kick off smoothly to begin with but may get stuck

up in midway because of paucity of funds leaving no room either to

roll back the project or to take it forward.

m) The present approach may not help in making Gurgaon DG set

free with a 24x7 quality power supply even by the deadline of

March 2019 given by the government. Going by the present

approach, it would take many years for the common consumers of

rest of the phases to fetch the benefits of the smart grid project.

45

The identified problematic areas across the city, which we normally

take care of before the next summers, would also remain

unattended.

In addition to above, it may also be kept in mind that the cities like

Ahmedabad, Mumbai and Kolkata where the network is

underground, it has taken a hard work of almost 50 years to reach

the level as it stands today. In Gurgaon also, the task to reach that

level in the next phases II, III & IV would take a minimum of next

15-20 years or so. The past experiences tell us that to spend even

Rs. 100 crores on a project has taken 2-3 years.

In addition to the above, the following points were also submitted

for perusal :

i) Augmentation of the undersized conductors on HT and LT Lines

ii) Bifurcation of overloaded 11 kV feeders

iii) To induct more nos. of distribution transformers

iv) Construct more nos. of substations at load centers

v) Have a ring-main at 66 kV and 11 kV levels

vi) Provide RMUs at Spur Lines to facilitate isolation of faults

vii) Take site specific decisions for erection of overhead or

underground system etc.

It was also decided to recommend implementation of SCADA only up

to the substation level and not unnecessarily spend money on the

field equipment for distribution level SCADA. Briefly if we say, the

major difference in the new approach is that one, the undergrounding

of system will be done only where it is absolutely necessary and two,

there will not be any redundancy at the distribution level. But there

would be ring mains at 11 kV level. RMUs will also be installed

46

wherever there are long spur lines for a quick isolation under fault

conditions.

To put up in precise manner the implementation of provisions under

the new approach, it is proposed to divide the present day Gurgaon

(Sectors 1 to 57) into 12 different smaller zones primarily based upon

the critical areas and the areas which we would anyway need to

develop and up-grade in the next 2-3 years to come. The cost of up-

gradation of distribution network to cater demand up to 2021-22

under the new approach will be around Rs. 600 crores and an equal

amount would be required subsequently when we plan the expansion

and up-gradation beyond 2022 up to 2031. HVPN would similarly

require around Rs. 2000 crores up to 2031 to add and upgrade their

system simultaneously with the growth. In a way, the anticipated

expenditure under new approach would come down to Rs. 3000

crores from Rs. 7000 crores.

The provisions under the new approach have been proposed in a

manner that these would be scalable upwards in future to meet the

requirements of a smart grid system. More importantly, it will be

possible to execute these up-gradations in next two years and the

consumers of whole of Gurgaon will simultaneously benefit from this

new approach.

To begin with, we have identified some of the problematic areas in

new Gurgaon and for the purpose of floating the NITs, we have

clubbed these areas into three groups. Estimated cost of these 3

NITs is around Rs. 75 crores. Similarly, we have identified the other

problematic areas in rest of Gurgaon and shall club them into another

9 groups, each costing around Rs. Rs. 50 to 60 crores. The total

estimated cost of these 12 groups would come out to be somewhere

around 550 – 600 crores.

47

Specifically coming to the jurisdictional area under DLF Subdivision,

of which the tender already stands floated under the original

approach and is due for opening on 4th November 2016, we can

easily address the problematic areas of Sushant Lok I and DLF

Phase III by planning site specific up-gradations at a cost of around

Rs. 50-60 crores as one of the 12 zones mentioned above.

The regulator will also not have any reservations on these

investments and it would be much easier to invest Rs. 600 crores in

next 2 – 2 ½ years and to recover the same through ARRs. We shall

not have to levy any kind of reliability surcharge. Also, since the

packages would be smaller, there would be a better competition

among the bidders, would help us in getting comparatively lower

prices and a simultaneous execution of the project across Gurgaon.

As the new approach envisages that all the old sectors i.e. 1 to 57

of Gurgaon would be taken up simultaneously, however, there

would be phases in terms of achieving functional objectives.

Accordingly, after considering all the aspects/differences of earlier

approach and new alternate approach to achieve the ultimate

functional objectives, Honb’le CM, Haryanahas approved the new

approach.

3.2 Need of Alternative Approach There is a need to instill confidence among the common

consumers that they won’t require the generator anymore. This is

possible only with the identification and up-gradation of the weak

links in the transmission and distribution system before the next

summer.These include undergrounding of HT network, bifurcation

of overloaded 11 kV feeders, augmentation of the undersized

conductors on LT Lines, to induct more nos. of distribution

48

transformers, construct more nos. of substations, have a ring-main

at 66 kV and 11 kV levels, and provide RMUs for early restoration

of supply.

As an alternative approach, to start with, identify the problematic

areas in new Gurgaon and for the purpose of floating the NITs,

and club these areas into small groups to resolve the power supply

issues in the shortest time. Estimated cost of these small groups

for each NITs costing shall be ranging between Rs. 125 to 200 Cr.

Creation of ring main at 11 KV level and providing of RMUs

wherever required for a quick isolation under faulty conditions.

It will be possible to execute these necessary up-gradations in next

two to three years which would take care of the load growth and

customer satisfaction.

To execute the works, Ministry of Power, Government of India to

be approached with revised DPR for sanction of funds under

Power System Development Fund (PSDF).However for the

balance amount funds can be arranged through Nigam’s own

funds for which the provision shall be made in the CAPEX.

The regulator will also not have any reservations on these

investments due to non-levy of any kind of reliability surcharge and

it would be much easier to invest the same through ARR.

3.3 Strategy for the Project as per alternate approach in various stages (I to IV)

As per the new approach and further discussion held at

management level it has been decided that the entire project for

Gurgaon i.e. Sectors 1 to 57 will be implemented in 4 stages, to

ensure proper integration of various features of Smart Grid. Stage

wise description of work planned to be executed is detailed out

below:

49

3.3.1 Stage-I The following points will be included in stage-I:

• All the overhead 11 kV lines shall be converted to underground

except wherever not feasible. The revamping of LT line is to be

done by re-conductoring/bifurcation/replacement with LT AB Cable.

Undergrounding of LT line is to be done in theft prone areas.

• The optical Fibre shall be laid underground alongside 11 kV HT line

to use the same for communication for SCADA scalability upto

distribution transformer level subsequently.

• As a consequence to the above decision, the RMUs to be provided

should be motorized (without FRTU) but having provision of

installing FRTU in future for enabling the SCADA functionality. The

RMUs shall be proposed at locations such as HT line T-off, HT

connection as sectionalizer, providing Ring configuration for

alternate backup. The LT Panels/ breakers shall be provided on 400

kVA and above rated DTs.

• The HT underground cable shall be laid in ring main configuration

with a load catering capability up to 2031.

• All the HT connections running on underloaded independent feeders

on same the route may be shifted/clubbed on one feeder with the

provision of ring main unit and redundancy within the ambit of HERC

regulations and adequately addressing the open access issue.

• For the implementation of provisions under the new approach, the

Sectors 1 to 57 shall be divided into 8 different smaller zones

starting with the most critical area and subsequently coving the

remaining area which would requireup-gradation in the next two to

three years in any case. The NIT cost of each phase should be kept

between 125 to 200 Cr. The completion period of each NIT shall be

kept as 24 months.

50

3.3.2 Stage-II • Supervisory control and data acquisition (SCADA) system shall be

implemented up to Substation level to start with.

3.3.3 Stage-III • Advanced metering Infrastructure(AMI) will be implemented in

stage-III in the entire Gurgaon (Sectors 1 to 57).

3.3.4 Stage-IV • During this phase LT network will be laid underground along with

provision for redundancy at LT network level.

• Also SCADA will be implemented up to Distribution transformer level

(Up to RMU).

3.4 Consolidated methodology of execution: The consolidated methodology for execution of the smart grid project

of Gurgaon with alternate approach is as under:

a. HT line:Bifurcation of overloaded 11 kV feeders having load

more than 150 Amps. The load projection upto 2031 to be taken

into account. The existing overhead 11 kV lines network shall

be converted into underground cable network using 11 kV

XLPE cables. The provision of overhead lines with ACSR/ cable

shall be kept sparingly.

b. LT line: Bifurcation/ Augmentation of LT line with ACSR

conductor/ cable and additional new LT line on need basis as

per site requirement and provision of additional poles in the

existing LT Line to reduce the span length. Provision of LT AB

Cable or LT Underground XLPE cable, primarily in village areas

falling within the urban area sectors 1-57 and the theft prone

areas, shall be made as per need basis.

c. Ring Main Units (RMUs): The Ring Main Units shall be

provided at HT line T-off, HT connection as sectionalisers,

51

providing ring configuration for alternate backup supply. The

RMUs to be installed under the project shall be motorized with

FPI but without FRTU and which shall have the SCADA

capability for connecting FRTU in future for enabling the

SCADA functionality.

d. Distribution Transformer: Considering the future load growth

additional distribution transformers as well as Augmentation of

overloaded distribution transformers shall be proposed. The

loading on the DTs shall be limited upto 70% of rated capacity.

e. LT panels/ protection: Provision of the LT/ACB or LT/MCCB

on the outgoing side of the 400KVA and above capacity DTs

shall be made. For below capacity DTs conventional erection

standards to be followed.

f. Load clubbing: All the HT connections running on underloaded

independent feeders on same route may be shifted/clubbed on

one feeder with the provision of ring main unit and redundancy

within the ambit of HERC regulations and adequately

addressing the open access issue.

g. SCADA implementation: SCADA to be implemented only up

to the substation level and in one go for whole Gurgaon (Stage-

II) for which consultant shall be appointed. However, the

provision of SCADA scalability till the distribution transformer

level shall be retained. Therefore, the optical fibre cable shall be

laid underground alongside HT simultaneously while laying the

HT line underground.

h. AMI implementation: The work of AMI shall also be

implemented in one go for whole Gurgaon at later stage (Stage-

III).

i. Project Area phasing: For the implementation of provisions

under the new approach, the Sectors 1 to 57 shall be divided

52

into 8 different smaller zones primarily based upon the critical

areas and the areas which we would anyway need to develop

and up-grade in the next 2-3 years to come. The NIT cost of

each phase should be kept around 125 Cr. to 200 Cr.

j. Funding and financial implication: As per the alternate

approach approved by Hon’ble CM Haryana the entire

proposed expenditure shall be met out through Nigam’s own

funds for which the provision shall be made in the CAPEX.

However, in addition, Ministry of Power, Government of India to

be approached with revised DPR for sanction of funds under

Power System Development Fund (PSDF). Originally the grant

of Rs. 273.20 Crores was sanctioned by the MOP,GOI under

PSDF against the earlier DPR of DLF sub-Divn area under

phase-I with an estimated DPR cost of Rs 1382 crores wherein

only certain components of the DPR for the project area were

sanctioned as the eligible components of BOQ. Now owing to

the change in approach covering the whole of Gurgaon

simultaneously a letter was written to ED, Power System

Operation Corporation limited, New Delhi vide this office letter

memo no Ch-24/ SCP-64 dated: 27 Oct 2016 wherein it has

been requested that the component of the LT undergrounding

and LT feeder pillars which was allowed under Rs 273.20 cr

sanction (which is actually 75% of the 364.27 crores) may be

allowed for the other eligible components but extending the

same for whole of Gurgaon. NLDC has replied to the above

letter vide letter dated 30-11-16 according to which the

committee has advised DHBVN to execute the approved DPR

with reduced scope and submit a fresh proposal for remaining

scope after getting the same approved from HVPN/HERC.In

view of the above in the DPR the same shall be highlighted and

53

only the funds for the additional work other than the earlier DPR

shall be claimed.Letters mentioned above have been placed as

Annexure-D.

54

4 Project Cost Estimation

4.1 Cost Estimate under Original Approach (DLF City S/D ie Phase-I of Part-I)

4.1.1 Key features of Original approach The key features proposed for establishment of Smart Grid in Gurgaon

(Original Approach)based on which cost estimation was carried out were as

follows:

• New 220/66/11 kV and 66/11 kV substations (GIS) for transfer of load

from existing overloaded substations with N-1 redundancy

• Augmentation of existing 66/11 kV substation to address ‘N-1’

redundancy

• Conversion of overhead system to underground cable. To start with

11 kV network will be taken up, which will be subsequently scaled

down to LT lines.

• Formation of 11 kV ring main by installing RMU (Ring Main Units)

• SCADA (Supervisory Control and Data Acquisition) and OMS

(Outage Management System).

• Optic Fibre Cable up to Distribution Transformer for bidirectional

communication between Consumer and utility

• Advanced metering system covering 4.4 lacs consumer till 2022.

• Load management at consumer level through Demand response and

Demand side management.

• Payment linked load shedding

• Integration of proposed system with R-APDRP

• Regulatory mechanism for Time of day tariff for all category of

consumers, tariff rationalization and mandatory energy efficiency

measures compliances

55

• The complete ownership for operation and maintenance will be with

DHBVN and HVPN, as the case may be, even in builder area after

the installation and commissioning of the new system.

• The existing street lights in the city and especially in the bye-lanes

are on DHBVN LT poles which will be removed when system gets

converted to underground and new underground street light system

will be laid alongwith the electrical system for which the concerned

department ie HUDA/MCG will bear the cost and deposit with

DHBVN.

• The operation and maintenance of newly installed system for atleast5

years after commissioning will be in the scope of executor

4.1.2 Estimate for DLF City Subdivision(Phase-1 of Part-1)

Based on above key features an estimate amounting INR 1382 Crores was

framed for DLF City Subdivision.The abstract of estimate is as tabled

below:

Sr.No. Description/Major head

of items Unit Quantity Total

Supply Cost

Erection Total (In Lacs)

In Lacs 1 HT Cables(Various

Sizes) KM 281.42 5338.45 232.11 5570.55

2 LT UG Line (Various sizes)

KM 1923.07 6248.14 271.69 6519.83

3 LT Feeder Pillar No.s 7451 13208.31 229.70 13438.02 4 RMU(Ring Main Units)

with FRTU & FPI No.s 563 4317.08 750.07 4392.16

5 Distribution T/F(11KV/.433KV)

No.s 240 2486.44 43.24 2529.69

6 Optical Fiber and PLB-HDPE Pipe

KM 259 322.54 14.02 336.57

7 Street Light No.s 11000 4395.35 8 Civil work for

foundation of DT/RMU/FP etc

No.s 8394 1189.96 1189.96


Mtr. 1043000 3563.50 3563.50

56

10 Fencing R/ Mtr 9711 371.21 32.27 403.49 11 RCC slabs and route

markers No.s 905430 2165.45 37.66 2203.11

12 PSS No.s 15 471.47 8.19 479.67 13 Cost of other minor

items/works L/S 1139.81 128.1 1267.91

14 5 years O & M @10% 4152.73 Sub-Total 50442.32

SCADA & OMS/DMS 1 SCADA & OMS along

with civil work required for the project

lot 10055

AMI (Including DTMU) 1 Field Equipment for

AMI & PLM lot 3409


lot 672

3 Field equipment for PQM & DTMU

lot 756

4 Consumer Education and Awareness

lot 10

Sub-Total 4847 TOTAL DHBVN-A 65344.32

TRANSMISSION-HVPN 1 Substations & Lines lot 70182

TOTAL (HVPN)-B 70182 Total Consultancies Charges-C(2 % of (A+B)) 2710.52 GRAND TOTAL (A+B+C) 138236.8

The NIT for up gradation of Distribution infrastructure falling under DLF City Subdivision under original approach has been dropped.

4.2 Cost Estimate under Revised Approach

4.2.1 Key features of revised approach

On account of discussions carried out in the meeting held on 25-07-16 and

28-10-16, following points were found in the best interests of the Project

based on which revised cost estimation has been carried out:

• All the overhead 11 kV lines shall be converted to underground

except wherever not possible. The revamping of LT line is to be done

by re-conductoring/bifurcation/replacement with LT AB Cable.

Undergrounding of LT line is to be done in theft prone areas.

57

• It was decided that ultimately we shall move towards SCADA but

since it is a technologically demanding scheme, therefore, initially the

SCADA shall be implemented up to 11kV level. However the

provision of SCADA being capable of serving till the distribution

Transformer level in future shall be retained. Therefore the optical

Fibre shall be laid underground alongside HT line.

• As a consequence to the above decision, the RMUs to be provided

should be motorized (without FRTU) but having SCADA capability for

connecting FRTU in future for enabling the SCADA functionality. The

RMUs shall be proposed at locations such as HT line T-off, HT

connection, as sectionalizer, providing Ring configuration for alternate

backup. The LT Panels/ breakers shall be provided on 400 kVA and

above rated DTs.

• The HT underground cable shall be designed in ring main

configuration with a load bearing capability up to 2031.

• All the HT connections running on underloaded independent feeders

on same route may be shifted/clubbed on one feeder with the

provision of ring main unit and redundancy within the ambit of HERC

regulations and adequately addressing the open access issue.

• The work of AMI shall also be implemented in one go for whole

Gurgaon at later stage.

• For the implementation of provisions under the new approach, the

Sectors 1 to 57 shall be divided into 8 different smaller zones

primarily based upon the critical areas and the areas which we would

anyway need to develop and up-grade in the next 2-3 years to come.

The NIT cost of each phase should be kept around 125-200 Crores.

The completion period of each NIT is to be kept as 24 months.

58

4.2.2 Revised estimate for Gurgaon sectors 1 to 57 Based on the features of revised alternate strategy as explained

above revised estimate for establishment of Smart grid in area under

Gurgaon Sectors 1 to 57 has been framed. The summary of estimate

is tabled below:

Sr.No. Description /Major head of items

Unit Unit Rate (In lacs)

Sector 1 to 57

Total Qty. Amt (In Lacs)

DISTRIBUTION SYSTEM


2 LT UG cables (Various sizes) KM 3.39 300 1017


4 RMU(Ring Main Units) No.s 7.80 3000 23404.05






No.s 0.14 6176 875.56


Mtr. 3.42 2820 9634.77

11 Fencing R/ Mtr 0.04 46760 1942.87





SCADA& OMS


Lot 7029

AMI(including DTMU)



Lot 1326


59


Sub - total 19691


TRANSMISSION-HVPN


TOTAL (HVPN) - B 0




4.2.3 Cost Estimate for DLF City Subdivision under revised strategy Based on the features of revised alternate strategy as explained above

revised estimate for establishment of Smart grid in area under DLF City

Subdivision,DHBVN has been framed. The summary of estimate is tabled

below:



DLF S/D (As per revised alternate

strategy) Qty. Amt.(In

Lacs) DISTRIBUTION SYSTEM


2 LT UG Cables (Various sizes) KM 3.39 50 169.5








No.s 0.14 1028 145.74


Mtr. 3.42 282 963.48

11 Fencing R/ Mtr 0.04 9711 403.49



60



SCADA& OMS


Lot( Taken as one time cost) 7029

AMI(including DTMU)



Lot 1326



Sub - total 4076

Total DHBVN A 26455

TRANSMISSION-HVPN


TOTAL (HVPN) - B 0




4.2.3.1 Funding of Revised estimate for DLF City Subdivision MoP,GOI will be approached for allocation of grant amounting Rs 273.20

croreswhich has already been sanctioned under PSDF to DHBVN for

establishment of Smart Grid in DLF City Subdivision(Phase-1 of Part-1 of

original approach).This fund will be utilised for development of Smart grid in

DLF City S/Div. as per revised alternate strategy.The funds will be utilised

by DHBVN in accordance with approved guidelines/procedures for funding

from PSDF.The detail of headwise component considered eligible for grant

under PSDF guideline 5.1(d) and calculation of grant allowed is placed as

Annexure-B.

61

4.2.4 Cost Estimate for Sectors 1 to 57 Gurgaon(Excluding DLF City S/D) under revised strategy Since a grant of Rs 273.20 crores for DLF City S/division has already

been sanctioned under PSDF, funding for establishment of Smart

Grid in DLF City S/Div.will be done by utilization of this grant.As DLF

City S/D is a part of Sector 1 to 57 Gurgaon and arrangement for its

funding has already been made, cost estimate for Sector 1 to 57

Gurgaon(excluding DLF City S/D)based on the features of revised

alternate strategy as explained above has been done as tabled

below:



Sector 1 to 57 (excluding DLF S/D under A.approach)

Qty. Amt. (In Lacs)

DISTRIBUTION SYSTEM 1 HT U/G Cables (Various Sizes) KM 19.75 2538 50135

2 LT UG Line (Various sizes) KM 3.39 250 847.5








No.s 0.14 5148 729.82


Mtr. 3.42 2538 8671.29

11 Fencing R/ Mtr 0.04 37049 1539.38





SCADA& OMS

62


Lot( Already taken as one time cost in DLF City S/Div.) 0

AMI(including DTMU)



Lot( Already taken in DLF City S/D Part) 0



Sub - total 15616


TRANSMISSION-HVPN


TOTAL (HVPN) - B 0



GRAND TOTAL (In Crores) 1338.40

Remarks:For the purpose of cost estimation under revised strategy the Unit

rates ofthe Major head of items have been taken as the unit rates

calculated on the basis of actual survey and planning of electrical

infrastructure for DLF City Subdivision (Phase-I of Part-I of Original

approach) as major scope of work excluding up gradation of LT network is

similar in both the approaches.Unit rates arrived for DLF City Subdivision

under original approach are placed as Annexure-C.

63

5 Transmission 5.1 Analysis and Challenges in Gurgaon transmission network Gurgaon has witnessed power demand growth in proportion to the district's

population growth rate. Peak Demand requirement has risen exponentially

in past one decade. In order to meet the rising demand, a nos. of steps has

been taken up to strengthen its Transmission and Distribution network.

Presently, Gurgaon district receives power from two (2) Nos. 400/220 kV

Substations namely Daultabad (945 MVA) , Secor-72 (630 MVA) and

Panchgaon (1000 MVA) with cumulative transformation capacity of 2575

MVA. 400/220 kV Panchgaon (1000 MVA) substation (PG) is

commissioned and is being interconnected with 220 kV Panchgaon (HVPN)

for dispersal of power. Part of the demand is also served through 220 kV

Samaypur, 220 kV Pali and 66 kV BBMB, Delhi Substations.

5.2 Present No. of Substations with installed capacity in Gurgaon

1.400/220 kV 3 No. (2575 MVA)

2.220/66 kV 6 No. (1760 MVA including 60 MVA BBMB)

3.220/33 kV 1 No. 100 MVA TF is placed at 220 KV S/S Sec-72, Gurgaon

4.66/11 kV 37 No. (2238.5 MVA)

64

5.3 Present Power Map of Gurgaon

5.4 Power Supply feeding points for Gurgaon Power is dispersed through Seven (7) 220 kV substation

(220/66 kV & 220/33 kV) at

65

Badshahpur,

Sector 52A,

IMT Manesar,

Daultabad,

Sector-56,

Sector-72 &

BBMB Delhi,

1860 MVA [220/66 kV, 1760 MVA & 220/33 kV - 100MVA].

Further in the downstream network, thirty four (37) nos. 66 kV

substations with installed capacity 2238.5 MVA

transformationcapacity feed power to DHVBN in Gurgaon.

5.5 Challenges in Gurgaon Transmission System Presently Gurgaon Transmission network faces challenges like inadequate

redundancy of 220 kV lines as well as power transformers. These 220 kV

transmission lines and power transformer get critically loaded during

contingency conditions and peak summer.

5.6 Transmission System Studies Gurgaon district witnessed about 1100 MW peak demand in 2012-13,

whereas it increased to 1250 MW & 1400 MW in 2013-14 & 2014-15

respectively, which is about 12-15% annualized growth rate. Demand

growth at such a rapid pace may not sustain in future and may get

moderated to about 8-10 % p.a. in coming years. However while doing

demand growth analysis, demand met through DG (10%) as well as DLF

Gas plant (104 MW), for year 2014-15 has been considered. Analysis

reveals that, peak demand requirement shall increase to about 2900 MW

by 2022.

66

To assure 24x7 quality power supply to the model Gurgaon Smart City,

Transmission and Distribution needs to be strengthened to meet massive

demand requirements rising on day to day basis with the horizontal and

vertical growth of the city. In this regard, based on inputs like demand data

(node wise), information about existing and planned transmission system,

network topology etc., detailed system studies have been carried for

planning of transmission system considering peak demand scenario by

HVPN.

5.7 Future Transmission Capacity In order to meet out the future load growth of Gurgaon at the rate of 8-10

%, transformation capacity addition at 400/220, 220/66, 220/33, 66/11 kV

has been planned under action plan 2021-22. Year wise transmission

capacity at various voltage levels up to year FY 2021-22 is illustrated in

tabular form below:

5.7.1 Existing/Proposed 400/220 kV Substations to feed Gurgaon area Details of Substation wise installed capacity up to Financial year 2021-22 is

Year Sector-72

Sstn. (In

MVA)

DaultabadSst

n. (In

MVA)

PanchgaonSstn.(In MVA)

Sohna Road

Sstn.(In MVA)

KadarpurSstn. .(In

MVA)

FarukhnagarSstn. .

(In MVA)

Total Capacity

(In MVA)

2016-17 630 945 1000 2575

2017-18 1630 1260 1000 3890

2018-19 1630 1260 1000 3890

2019-20 1630 1260 1000 1000 1000 5890

2020-21 1630 1260 1000 1000 1000 1000* 6890

2021-22 1630 1260 1000 1000 1000 1000 6890

*In Principle approval for 630 MVA(2×315 MVA) but to be revised for 1000

MVA (2×500 MVA)

67

5.7.2 Transformation Capacity FY 2016-17( Action Plan 2021-22)

2016-17

Present No. of Sub-stations with Installed

Capacity.

Proposed Augmentations

in No. with capacity ending

2016-17

Proposed new Sub-Stations in

No. with Capacity ending

2016-17

Final sub-stations with

Capacity ending 2016-17

Voltage level

220/66 KV

220/33 KV

66/11 KV

220/66 KV

220/33 KV

66/11 KV

220/66 KV

220/33 KV

66/11 KV

220/66 KV

220/33 KV

66/11 KV

No. 6 0 37 1 0 4 4 0 4 10 - 41

Capacity ( MVA)

1760 100 2238 60 0 66.5 1040 200 229 2860 300 2534


2017-18

No. of Sub-stations with

Installed Capacity starting

2017-18

Proposed Augmentations in No. with capacity ending 2017-18



2017-18

Final sub-stations with

Capacity ending 2017-18

Voltage

level

220/66 KV

220/33 KV

66/11

KV

220/66 KV

220/33 KV

66/11 KV

220/66 KV

220/33 KV

66/11 KV

220/66 KV

220/33 KV

66/11 KV

No. 10 - 41 2 1 23 - - 3 10 - 44

Capacity ( MVA)

2860 300 2534 220 100 476 - - 136 3080 400 3146

68


2018-19



2018-19




2018-19

Final sub-stations with Capacity

ending 2018-19

Voltage

level

220/66 KV

220/33 KV

66/11

KV

220/66 KV

220/33 KV

66/11 KV

220/66 KV

220/33 KV

66/11 KV

220/66 KV

220/33 KV

66/11

KV

No. 10 - 44 - - 9 1 6 5 11 6 49

Capacity ( MVA)

3080 400 3146 - - 164 320 1200 284 3400 1600 3594


2019-20



2019-20




2019-20


ending 2019-20

Voltage

level

220/66 KV

220/33 KV

66/11

KV

220/66 KV

220/33 KV

66/11 KV

220/66 KV

220/33 KV

66/11 KV

220/66 KV

220/33 KV

66/11

KV

No. 11 6 49 - - - - - - 11 6 49

Capacity ( MVA)

3400 1600 3594 - - - - - - 3400 1600 3594

69


2020-21



2020-21




2020-21


ending 2020-21

Voltage

level

220/66 KV

220/33 KV

66/11

KV

220/66 KV

220/33 KV

66/11 KV

220/66 KV

220/33 KV

66/11 KV

220/66 KV

220/33 KV

66/11

KV

No. 11 6 49 - - - 1 - 1 12 6 50

Capacity ( MVA)

3400 1600 3594 - - - 320 - 63 3720 1600 3657


2020-21



2020-21




2020-21


ending 2020-21

Voltage

level

220/66 KV

220/33 KV

66/11

KV

220/66 KV

220/33 KV

66/11 KV

220/66 KV

220/33 KV

66/11 KV

220/66 KV

220/33 KV

66/11

KV

No. 12 6 50 - - - - - - 12 6 50

Capacity ( MVA)

3720 1600 3657 - - - - - - 3720 1600 3657

70

5.8 Installed capacity/Maximum demand at various distribution

Installed capacity/Maximum Demand in Year 2016-17 &approved

capacity/anticipated demand in Year 2021-22 at various distribution levels

is illustrated below:

* The total installed capacity of 3657 MVA up to 2021-22 also includes 268

MVA capacity of Private Developers . Besides it, DLF is having a demand

of 120 MVA at 66 KV level for its 2 No. (60 MVA each ) 66/11 KV sub-

stations to be constructed in Sector-24 & 25 GGN by DLF.

71

6 DISTRIBUTION

6.1 Analysis of existing infrastructure and Identification of Challenges DHBVN is one of the good distribution utilities in India, striving to set the

best standards in operational practices. The distribution business in

Gurgaon is running at comparatively low AT&C losses which reflect the

efforts made in the recent past to bring down the losses and to ensure high

collection efficiency. However, on front of ensuring reliable and quality

power supply to its consumers 24×7, DHBVN is lagging in some areas of

Gurgaon due to various reasons. Factors hampering DHBVN performance

in ensuring reliable and quality power supply in Gurgaon despite the

availability of surplus power in the state are listed below:

6.1.1 Radial electrical Network Electrical network at 11 kV voltage level in Gurgaon is a radial network

which practically means that the 11 kV feeders emanating from a 220/66/11

kV substation feed their respective areas in isolation and in case of any

fault occurring in the line, the whole area gets switched off till such time the

fault is attended. Also, since there is no-ring main system at 11 kV level,

there is hardly any possibility of restoring the supply on any section through

feeding back from another source.

6.1.2 Policy of Independent feeder As per existing policy of DHBVN, a consumer can opt and demand for

single point supply on 66KV/33KV/11KV feeder if the sanctioned load is

250 kVA or more. However, due to the commercial constraint of billing of

consumer from Substation end, it is not possible to back feed the load of

consumer in case of a fault in main feeder of consumer.

72

6.1.3 Non-availability of Right-of-Way

At present, because of a large number of Urban and Independent feeders,

right-of-way for erection of a new feeder is extremely difficult and not at all

possible in most of the cases.

6.1.4 Multiple 11 kV Feeders on a Pole Because of erection of multiple feeders on single pole due to right-of-way

problems and congestion, permit to work (PTW) has to to be taken on all

the feeders running on a pole with multiple circuits, if fault occurs in any of

these bunched feeders. It leads to unnecessary loss of sale of power and

reduces reliability of supply.

6.1.5 Aged and poor LT distribution network LT distribution network in Gurgaon sector 1 to 57 is overhead in most of the

cases. Conductor of LT distribution feeders is aged and has rendered

undersized due to increase in load growth over period of time thereby

leading to increase in frequency of outages due to conductor snapping.

6.1.6 Manual Fault Rectification Process of fault identification and isolation/back feeding of faulty portion of

a 11 kV feeder is manual. It leads to long outage durations and reduces

reliability of power supply.

6.1.7 Unregulated Constructions There are certain pockets in Gurgaon City Like U block, S block DLF

Phase-III where plot owners are building plots up to 7 storeys on plot size

measuring as low as 60 sq. yards or even 40 yards. Because of these types

of unregulated constructions, load is growing in an unpredictable and

exponential manner. DHBVN is not able to keep up pace with load growth

in such pockets due to narrow lanes hampering erection of overhead

infrastructure and unavailability of land for creation of new Plinth mounted /

Pole mounted substations. Unless construction in such areas is regulated

73

by DTCP/Municipal Corporation, load requirement of these areas will

always create pressure on existing electrical infrastructure.

Other Challenges include Capacity Inadequacy, Inadequate reactive

compensation, absence of SCADA & Automation, Poor voltage regulation

in distribution feeder, overloading of transformers and most of all, no

redundancy level at all.

Existing electrical infrastructure and shortcomings are illustrated below:

74

Fig. A: 7 Storey building under construction on a 60 sq.yd. plot in U Block DLF-III

75

Fig. B:Other Multi storey buildings under construction on 60 sq.yd. plots in U Block DLF-III

76

Fig C: Multiple 11 KV Feeders on same poles

77

Fig. D: Right of way problem due to Multiple 11 KV Feeder Networks

78

Fig. E: Narrow Lanes leading to issue to safe Horizontal clearance

79

Fig.F: Open H-Pole substation posing a threat to human and stray animals life

80

Fig G: Multiple LT Networks passing through LT Poles

Fig. H: Overcrowded LT Poles with meters and Outgoing Service Lines

81

7 Developing the Smart Grid

In this era of advent of modern technology into the electrical system, it is

possible to make the present system more robust and economically viable

simultaneously using Smart Grid technologies and IT interventions. These

technologies co-ordinate the needs and capabilities of all the stakeholders

of power supply chain viz. generators, grid operators, distributor, end users

and facilitate electricity market in a way to optimize asset utilization,

resource optimization, control and operation with minimum losses and

enhanced quality. This ensures more reliable power along with smart

utilization of available technology to make today’s cumbersome and

sophisticated activities easier and accurate. Most importantly, consumer

satisfaction becomes the ultimate motto and customers are empowered to

interact with the utility. Therefore, smart grid technologies in the field of

Monitoring & Measurements, Communication, Control & Automation, IT

infrastructure, energy efficiency etc. shall be integrated with present system

insectors from 1 to 57,Gurgaon.

82

7.1 What is Smart Grid Typical structure of the Smart Grid is shown at Figure-1.

Figure-1: Typical smart grid structure

Major intelligent enabling technologies which are building blocks of the

“Smart Grid” are given as under:

• Advanced Metering Infrastructure: It consists of Smart Meters,

Communication Network, Head End equipment, Meter Data

Management System and Analytics. It enables online energy

consumption visualization and helps in controlling leakages of power by

facilitating immediate temper alert and short duration energy audits.

Efficiency of system is also improved through enablement of automated

83

reading, demand response, remote load dis/re-connection, control of

critical & non-critical loads etc.

• Integrated Communication System: Communication system

comprising of optical fibre network, GPRS, RF Mesh, PLC etc., utilized

by various Smart Grid Technologies for communication of data &

information between control centre and consumers / equipment.

• Peak Load Management: Using advanced metering infrastructure

information, peak load management is done by way of variable intra-day

tariff, load curtailment, device control mechanisms etc.

• Outage Management System: It increases reliability of the power

supply and reduces outage frequency & duration. Faults types &

locations are automatically reported to control centre and maintenance

crew is dispatched in optimized way directly to fault location depending

upon location of team & fault. Also various monitoring devices are

installed which help in checking healthiness of equipment.

• Renewable Energy: It is an essential part of Smart grid to reduce the

dependency on conventional resources and to make cities more

sustainable and clean.

• Distributed Generation: Distributed resources like solar, biomass,

wind etc. reduce transmission and distribution grid requirements and

feed loads directly.

• Energy Storage: Energy Storage helps in balancing intermittency,

uncertainty and variability of renewable resources in any grid and make

them more stable & secure.

• Electric Vehicle: Use of electric vehicles reduces CO2 emission by

transportation sector and make environment healthier. It also helps in

grid balancing as it may be used to absorb excess power in grid, or to

84

supply power back to grid at peak times through enabling of suitable

market mechanisms.

• Power Quality Management: Sensors & equipment installed at

different nodes of Smart Grid measures power quality and activate

suitable mitigation techniques to make power free with electrical

pollution.

The various attributes of Smart Grid are as shown in the Figure 2

Figure 2: Smart grid attributes

85

Considering present system architecture and progression of initiatives like

R-APDRP, it is emerged that following Smart Grid attributes/technologies

would be appropriate for implementation in Gurgaon Sectors-1 to 57:

(i) Advanced Metering Infrastructure (AMI)

(ii) Peak Load Management (PLM)

(iii) Power Quality Management (PQM)

In addition to the above, implementation of Real time Distribution

Transformer Monitoring shall also be done.

The details of above implementations are described in following

paragraphs.

7.2 Advanced Metering Infrastructure (AMI) Advanced Metering Infrastructure (AMI) is a system that measures,

collects, transfers and analyzes energy usage and communicates with

metering devices either on request or on a schedule basis. This system

includes Smart meters, communication systems, data concentrator units,

customer associated systems, Meter Data Acquisition System (MDAS),

Meter Data Management (MDM) software, and business analytics. AMI

shall be installed in Gurgaon Sectors-1 to 57 of Gurgaon to improve

visualization of energy consumption & power quality at consumer level and

facilitate peak load management through demand side management /

demand response. AMI enables two-way communications hence has the

potential to communicate from the utility to the meter and vice-versa. Utility

can have online consumption record of each individual in fifteen (15)

minutes time block which will be helpful in analyzing consumption pattern &

forecasting energy usage. At the same time consumer can access online

data for their consumption, which would help them in controlling monthly

bills. Automatic meter recording would mitigate requirement of manual

86

process of meter reading, which would make billing system more accurate,

efficient and fast. Using two way communication system pricing signals may

also be sent to consumer participating in demand response mechanism.

With the available data received in advanced metering infrastructure, utility

has following tools to make system smart:

i. Energy audits can be done at distribution transformer level to

check theft

ii. Load pattern of individual consumer can be observed

iii. Withdrawal of power above sanctioned load may be checked

iv. Tampering may be checked in real time

v. Control actions from control centre for load curtailment may be

taken

vi. Remote connection / disconnection is possible

vii. Sending alert to consumer for higher load withdrawal, bill non-

payment etc. is possible

viii. For variable pricing, signal transmission is possible

DHBVN is implementing various IT related initiatives like GIS mapping,

billing application, and consumer indexing etc. in its areas. Since these

applications are also required for Smart Grid project, setting up separate

system would not be prudent and existing set up shall be also utilized for

Smart Grid attributes to economize cost. GIS mapping, Asset Mapping,

Consumer Indexing and billing application etc. covered under the RAPDRP

/ other schemes shall be integrated with Smart Grid system.

Under advanced metering infrastructure, smart meters shall be installed for

all domestic, commercial, industrial, HT, street lights and other consumers

as identified by DHBVN. Meter Data Acquisition System (MDAS), Meter

Data Management System (MDMS) along with necessary hardware /

87

software shall be installed at control center. Interface of various IT

applications / processes installed in R-APDRP shall be done as below:

1. Billing Application– Billing data of Smart meters installed in Smart

Grid shall be pushed to billing application installed in R-APDRP at the

end of billing cycle.

2. GIS mapping and consumer indexing data shall be integrated with

advanced metering infrastructure applications and periodic

synchronization/ updating shall be carried out.

A proposed layout of Advanced Metering Infrastructure component is

shown in Figure-3.

Figure-3: Proposed architecture of AMI

Communication medium between Smart Meters & Data Concentrator Unit

shall be RF / PLC. Data from DCU to MDAS shall be communicated

through GPRS/OFC.In control centre Meter Data Acquisition System

DHBVN Meters

88

&Meter Data Management Software shall be hoisted, which will collect,

store and analyze data received from DCU / Meters.

Suitable cyber security system shall be installed to protect the system from

viruses and intrusions. Security system shall create different zones,

separated with firewalls. Inner zone will be accessible to operators in

DHBVN, which would consist of workstations, servers for all applications,

data archive server, storage devices and network management system.

The middle zone subsystem will have centralized management console,

web portal / consumer portal servers. Outer zone would be accessible to

the external users and other integrated systems. All the servers/stations will

be equipped with Host based Intrusion Detection & Prevention System

(IDPS). Patch management tools will be provided to update the patches

received by the various OEMs e.g. patches for anti-virus, firewalls,

application software etc.

MDAS shall be the core application for interface to the field devices. It shall

perform following functions:

• Acquisition of meter data, i.e. poll meters for data collection. On

demand read and ping of meters

• Two way communication with the meter, including load control

• Sending remote firmware upgrades/programmable parameters to

meters/ DCU

• Sending load control signals to the meters

• Maintaining time sync with DCU / meters

• Sending Connect/ Disconnect, and pricing signals to the Smart Meter.

Control signals, event messages etc. shall be handled on priority.

• Reporting communication history for meters and DCU

• Supporting encryption of data transmission for secure communication

89

Meter Data Management system shall take information from MDAS for

further analysis and structured presentation of the same to user. It shall

have following functions:

• Asset Management

• AMI Installation Support

• Meter Data Analysis

• Exception Management

• Service Orders Generation

• Customer Service Support

• Reporting

• Revenue Protection Support

• Demand Control/Demand Response Support

• User Friendly Interface

• OMS

• Integration with other Systems

Implementation of complete infrastructure as mentioned above shall

provide an excellent tool in the hand of utility for operation of efficient,

accurate, intelligent and customer friendly metering system. Details of

implementation have been discussed below:

5.2.1 Number of Smart Meters Required

Project area of Part I i.e.sectors 1 to 57,Gurgaonhas total 224363 Nos. of

consumers. Following considerations have been made to arrive at the

actual quantities of smart meters for the project:

• Energy meters on distribution transformer are being installed under

R-APDRP, therefore these locations have not been considered here

for smart meters under AMI. MDAS/MDM being provided under R-

APDRP would be integrated with MDAS/MDM of AMI to receive DT

meter data for energy audit.

90

• Quantity of different types of the smart meters is based on consumer

master data of project area as on 31.10.16.

Accordingly 224363 consumers shall be covered for smart meter

installation under AMI. Break up of Smart Meter requirement is shown in

the following table:

Table -1: Smart meter requirement

Sl. No.

Type of meter No.

1. Single phase whole current meter 128073

2. Three phase whole current meter 90784

3. LT CT operated meter 3854

4. HT 11 KV CT operated meter 1648

5. HT 66 KV CT operated meter 4

Total

224363

7.3 Peak Load Management (PLM) During peak load conditions, utilities overdraw power from the grid defying

entitlement schedules, which impacts grid reliability and costly power due to

Unscheduled Interchange (UI) charges. At the same time utility need to

setup infrastructure to meet the peak load whereas at other times such

infrastructure largely remains under-utilized. Therefore for economic

operation of the power network, peak load management is an essential

requirement. The goal of peak load management is to encourage the

consumer to use less energy during peak hours, or to move the time of

energy use to off-peak times such as night-time and weekends. It is the

modification of consumer demand for energy through various methods such

as financial incentives and partial curtailment. Peak demand management

does not necessarily decrease total energy consumption, but could be

91

expected to reduce the need for investments in networks and/or power

plants. Load shifting involves shifting energy consumption to another time

period, typically when prices/consumption are lower.

The PLM system collects information from various other systems. It takes

data from the Load forecast software, the power scheduler, and the

availability sub systems. Based on these inputs power demand-supply is

determined, deficit/surplus is worked out and demand response signals are

sent out to the consumers. Peak Load Management does not mean load

shedding. Figure - 4 shows the peak load shifting.

Figure - 4: Peak load management

Peak Load Management works in two ways:

a) Demand Response (DR):Demand response refer to mechanisms used

to encourage consumers to voluntarily trim electricity usage at specific

times of the day (such as peak hours) during high electricity prices

(Time of Use tariffs), or during emergencies (such as preventing a

blackout). Depending on the generation capacity, however, demand

response may also be used to shift demand (load) from peak to off-peak

at times of high production and low demand. In demand response the

consumer voluntarily manages his demand in response to some

signals/incentives given by the utility. Dynamic/ ToU pricing of electricity

92

and other incentives/schemes are communicated to the consumer via

smart meter/ Web and SMS. The consumer responds by reducing

consumption by agreed percentage or limiting consumption to agreed

kW. b) Demand Side Management (DSM):In case of demand management,

the utility in a sense "owns the switch" and sheds loads only when the

stability or reliability of the electrical distribution system is threatened. It

works in three ways: (i) Settable Relay: In this mechanism smartmeters have relay with

switch, which is designed for operation till a threshold load. Any

increase beyond threshold load, operates the relay and switch is

opened to cut-off power supply. Re-connection attempts may be

carried out as per defined number of times. In reconnection attempts

if load is reduced then connection is made otherwise it is locked and

opened with intervention of utility. (ii) Critical & Non-Critical load ckt: Wherever consumer agrees to

segregate load at meter point between critical and non-critical loads

smart meter will feed two separate load circuits. The relay & switch of

non-critical load ckt is opened during peak load times.

In Gurgaon Sectors-1 to 57 management of peak demand would be done

using smart meters, which have been proposed to be installed in consumer

premises as part of advanced metering infrastructure. Peak load

management application would be installed in conjunction with advanced

metering infrastructure software to manage peak load in following ways:

7.3.1 DR and DSM for All Consumers Peak load management through demand response & demand side

management through settable relay / switch in smart meters shall be

implemented for all the consumers. Implementation shall be as below:

93

i. ToU tariff shall be notified for all the consumers with significant

difference between peak duration tariff and off-peak duration tariff so

as to encourage them to participate in demand response. Two way

communication facilities available with smart meters shall help in

sending variable price signal / alerts to consumers for reducing load.

ii. In demand side management using settable relay, load curtailment

shall be enacted during peak load hours to reduce the power

consumption by users. Users below the load allowed at that time shall

remain connected and if their consumption exceed the allowed level,

they will be disconnected after due warning. Reconnection attempts

shall be allowed three times in every five minutes. Failing to reduce

the load, disconnection shall be locked for thirty minutes.

Popularization of this technique will help in limiting the loads similar to

inverters and batteries.

7.3.2 Power Quality Improvement Power quality is a measure of the fitness of electrical power fed into the

consumer devices. Without good quality power, an electrical device (or

load) may malfunction, fail prematurely, become economically unviable due

to losses or not operate at all. There are various parameters like voltage

sag/swell, low power factor, current/voltage harmonics, and transients etc.

which are related to quality of power and deviation in their value from

reference results into poor quality of power.

The power system in project area of Gurgaon is designed for a balanced

three phase operation. However, unbalanced operation, harmonic currents

etc. cause extra losses in the system. Similarly over voltages, transients

etc. cause additional stress to the insulation. Low power factor and large

harmonic content increase the losses and reduce the active power

transmission capability of the system. The list of power quality issues

generally present at the distribution level is quite extensive. However, the

94

most prominent ones that have direct impact on the system efficiency and

security include harmonics, unbalance, poor power factor and zero

sequence components (resulting in neutral current). These are classical

power quality issues, which are addressed by various passive solutions.

However, advancements in power electronics and control have led to much

efficient active solutions generally referred to as Active Power Filters. A

typical schematic of active power filter is shown in figure below.Active

Power Filters are considered to be a single window solution virtually for all

the current related issues. It may be noticed that active filters are shunt

devices that inject a current comprised of all notorious components required

by load (harmonics, negative and zero sequence, reactive component etc.)

that are unhealthy for the overall system and cause high losses.

Technically, an active filter is based on STATCOM principles, with a DC

bus formed by a large capacitor. Thus, modern active filters provide highly

flexible solutions, simultaneously addressing issues like current harmonics,

load unbalance in phases, reactive power demand, neutral current etc. with

priorities configurable by the user. It may be noted that active filters provide

an indirect solution to voltage harmonics issue by limiting current harmonics

travelling into the distribution system.

Figure -5: Schematic for active power filter

95

In view of the above, deployment of active power filter at 100 distribution

transformers shall be carried out. This would not only make the system

more efficient and reliable but also would help in enhancing the awareness

and understanding of power quality within the utility. In order to identify the

suitable DTs for installation of active filters, we need to carry out power

quality measurement survey of distribution transformers at different

locations in project area. After measurement & analysis of recorded data for

the distribution transformer, top 100 most suited one will be recommended

for installation of active power filter equipment because of large content of

harmonic currents, unbalancing etc.

7.4 Distribution Transformer Monitoring Unit (DTMU) Distribution transformers are very important equipment near end

consumers, which are needed to be kept healthy from the point of view of

utility as well consumers as any defect in these would result into outage of

many consumers and considerable revenue loss to utility. Distribution

transformers are generally installed in any locality based on the loads

requisitioned by respective consumers and estimated future requirements.

However due to economic uplift of society and penetration of new

appliances in consumer’s premises continue to grow, which outpace the

estimated rise in load considered by utility earlier. Any carelessness in

monitoring of distribution transformers may soon result into overloading

operations and subsequent failures. Further leakage of oil, heating of

terminal connection etc. are some of the other reasons which cause failure

of distribution transformers. Therefore Distribution Transformer Monitoring

Units (DTMUs) are becoming necessary to be installed for healthy

operation of systems.

DTMU is the equipment through which real time monitoring of oil

temperature, oil level & LT side load current / parameters of distribution

transformer can be done. Any abnormality in these parameters triggers an

96

exception event and reports to control centre for further actions. Based on

the DTMU data, maintenance teams can also take proactive measures to

repair /replace the distribution transformer.

Distribution Transformer Monitoring Unit are proposed to be installed on all

the transformers owned by DHBVN as a part of Smart Grid initiative in

project area of Gurgaon. The installation of DTMUs will provide online

information of loading, oil temperature & oil level which may prevent failure

of transformer on account of overloading, low oil level, miniature internal

faults etc. There are total 3521 nos. distribution transformers on which

DTMU’s have to be installed.

7.5 Smart Grid Control Centre A Smart Grid Control Centre shall be setup in any existing facility to be

decided later on, where all the software applications along with required

hardware systems shall be installed. All the field equipment shall send the

data to the control centre, where processing of the same shall be done

using software applications to get useful information. The control centre for

Smart Grid project implementation shall require three discrete areas for

operation control (5m X 5m), server (4m X 4m) and UPS & battery (4m X

4m). Smart Grid control centre will require 10 KVA UPS power for operation

of servers, workstation, operation console etc. Building & other civil works

have not been considered in this report.

97

8 BENEFITS OF SMART GRID INITIATIVES

Smart Grid project is being done as an initiative to embed new technologies

in distribution system in small scale and successful implementation would

draw the way forward for large scale implementation. Therefore for such a

project finding economic viability and feasibility would be prejudice as

qualitative benefits are of paramount importance. Large scale

implementation in future may only prove economies of operation. Benefits

of proposed initiatives in project area are mentioned below:

8.1 Benefits of Advanced Metering Infrastructure Benefits from AMI may be categorized as:

System Operation Benefits: These are primarily associated with reduction

in meter reading and associated management and administrative support,

increased meter reading accuracy, and improved utility asset management,

easier energy theft detection and easier outage management.

Customer Service Benefits: These are associated with early detection of

meter failures, billing accuracy improvements, faster service restoration,

flexible billing cycles, providing a variety of Smart Grid features like time-

based tariff options to customers, and creating customer energy profiles for

targeting Energy Efficiency/Demand Response programs.

Financial Benefits: These accrue to the utility from reduced equipment

and equipment maintenance costs, reduced support expenses, faster

restoration and shorter outages.

Details of the benefits due to AMI are described below:

8.1.1 Reduction in Meter Reading Cost In AMI, meter reading shall be communicated to control room automatically

in every 15 minute time block. This will reduce meter reading cost on

account of reduction in manpower.

98

Presently all the meters proposed to be replaced with smart meters

(224363 Nos.) in Smart Grid project are manually read for which 80 meter

readers have been deployed. Cost savings through the reduction in manual

meter reads will be realized through a reduction in meter readers thus

reduction in both in-house and contractor labor costs. Meter reader

workforce reductions shall occur over the course of the AMI implementation

period, and DHBVN may plan to realize these workforce reductions through

natural attrition and work re-assignment over time. Quantifiable benefits

related to manual meter reading savings are expected over business case

time horizon.

8.1.2 Reduction in Field and Meter Services Smart metering and communication infrastructure enables utilities to

perform several functions remotely that would otherwise require a field visit

to the customer premise. As a result, significant cost savings through the

reduction in the number of personnel for field and meter services can be

achieved. Benefits in this area can be seen in the reduction in manual

disconnect / reconnect of meters, single consumer outages, need for

manual re-reads, as well as customer equipment problem.

8.1.3 Reduction in Off Cycle Trips Remote connect / disconnect feature of AMI smart meters enables utilities

to turn on and off services for new and cancelled accounts remotely without

a field trip. This benefit not only applies to the ability to turn on and off

services for regular move-in / move-out of customers, but also provides the

ability to cancel service for non-paying customers. As a result, significant

cost savings can be realized through the reduction in need for personnel

and transportation costs to turn on / off services. As a result of AMI, cost

savings will also be seen through the time saved in off cycle reads / special

reads due to reduction in meter access challenges.Approximate150000

nos. trips are carried out in part I project area monthly for manual

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disconnection/connection, manual off-cycle reads, special meter reads etc.

in one month, which may be reduced by implementation of AMI.

8.1.4 Reduction in Outage Field Trip AMI implementation is expected to result in cost savings associated with

reduced outage field trips to customer premises. With the ability to provide

near real-time power and outage status information, AMI systems are able

to test for loss of voltage at the service point and shall be able to detect

outage conditions as well as obtain restoration status indication. As a result,

“OK on Arrival” field trips will be virtually eliminated, in AMI areas, thereby

leading to cost savings.With AMI, DHBVN will be able to determine whether

the cause of an outage is the result of an electrical problem with the

customer’s equipment. This automated determination will help save

dispatch labor for customer incidents that involve equipment failure.

8.1.5 Reduction in Unaccounted Energy Unaccounted Energy in the areas of meter tampering, energy theft, meter

inaccuracy, and dead / stopped meters results in significant revenue loss

for utilities. Through the use of smart meters and sophisticated MDM

systems, unaccounted energy can be detected early and revenue losses

related to unmetered energy can be reduced.

8.1.6 Theft / Tamper Detection & Reduction AMI systems significantly aid in the early detection of meter tampering and

energy theft. Smart meters can detect tampers like Meter Cover open

detection, Neutral disturbance, Magnetic Interference etc. and these tamper

alerts are communicated immediately to control centre. Also energy audit

for each integration period is carried out in control centre applications for

predefined set of meters. Any discrepancy in energy reading of main meter

and sum of energies of subordinate meters is found by analytical engines

and same is notified to operators. Also analytics software allows

identification of anomalous patterns of energy consumption by consumers

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which are may be due to theft and tampering. As per historical data, 1.66%

is the billing inefficiency losses. This component includes energy loss due

to theft and tampering and with implementation of AMI these losses are

likely to reduce.

8.1.7 Faster Identification of Dead Meters Smart meters have feature to send power loss signal or last gasp message

to control centre. Thus implementation of AMI systems helps utilities in

quick identification of dead and/or stopped meters that can no longer

measure electricity consumption. Such signals/ messages are correlated

with signals/ messages received from other smart meters in that locality. If

found an isolated case then possibility of being dead is confirmed and

notified to operator. This early identification helps utilities to take steps

quickly towards repairing or replacing the dead meter, thereby reducing

potential revenue losses. Non-technical losses before billing include such

losses, which are likely to be reduced after implementation of AMI.

8.1.8 Improved Distribution System Savings It is expected that AMI shall help in improvements in the distribution system

planning efforts. AMI will provide detailed information across the distribution

network that can be used to optimize investments in infrastructure

improvements. Data available by AMI like Interval (time-based)

consumption data at the customer level (and ability to aggregate up to

transformer and circuit levels), voltage information collected at each

premise, momentary outage information etc. shall help in better

management of system.

8.1.9 Improved Distribution System Management Interval consumption data can be aggregated at the transformer level to

help identify under-used and overloaded transformers, as well as to

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properly size replacement transformers. Information received through AMI

will provide more granular level system health and performance details.

Using more detailed information from AMI enables DHBVN to more

accurately forecast load growth and evaluate system investments resulting

in improved asset planning and strategies.

Further due to peak load management up-gradation work of distribution

system may be deferred. We consider that approx. 125 MW (10% of peak

load) peak shaving may be done using suitable peak load mechanism. For

this 125 MW power flow, distribution system expansion may be deferred by

at least one year resulting into saving of interest cost on borrowed capital.

8.1.10 Operational Efficiency Improvement An important benefit of AMI is the cost savings realized through efficiency

improvements in customer call volume and management. Meter reading

errors are expected to be virtually eliminated and the need for calculation of

estimated bills due to access issues will be significantly reduced, in AMI

areas. Efforts to raise awareness regarding AMI through marketing

campaigns and customer education will increase customer adoption of self-

service leading to an overall reduction in call volume. The potential to

reduce float between meter read and customer billing will also drive greater

benefits for DHBVN.

8.1.11 Reduction in Estimated Bills The ability to remotely read meters on a frequent basis greatly reduces bills

based on estimation that often result from meter access issues that

currently prevent meter readers from obtaining reads in hard to access

areas at the customer premise. Fewer customer service resources are thus

expected to review exception reports, resolve billing errors and process

adjustments.

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8.1.12 Reduction in Customer Call Volume Comprehensive marketing campaigns and customer awareness programs

will educate customers about the self-service options available to them

throughout the AMI roll-out. DHBVN receives large number of calls annually

related to customer inquiries. DHBVN is currently planning on further

developing its customer self-service capabilities, including web and IVR

enhancements channels. DHBVN plan to increase the self-service

marketing efforts during the AMI roll out, encouraging portal use and

promoting self-service within AMI communications. As a fair estimate we

can expect a 5% reduction in call volume as a result of greater self-service

adoption. This will also be driven by lower bill inquiry call volume due to

reductions in bills based on estimation. The reduction in call volume over

the life span will result in cost savings.

8.1.12.1 Reduction in Float between Meter Read and Customer Billing

AMI is expected to enable all accounts within AMI territories i.e. project

area to be billed on the monthly basis on the billing window. Currently bills

which are produced during different days will now be generated

simultaneously as a result of AMI. This will accelerate DHBVN’s revenue

stream and improve its cash flow.

8.2 Benefits of Peak Load Management PLM programs like demand response/demand side management will help

DHBVN in pecuniary benefits in following terms:

A) Reduction in Power Purchase Cost: Generally time of the day and

season of the year plays an important role in peak power

requirements. It may be 1-2% of the total time, but infrastructure

creation is required to meet such load only. Therefore peak shaving

benefits utility as capital infusion in infrastructure may be deferred for

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some years depending upon peak load reduced. This capital may be

used to service operational requirements making utilities more

competitive.

B) To meet peak load, utilities make arrangement of extra power by short

term purchases through bilateral agreements or energy exchanges.

Any short term power purchase that too in peak hours is always

costly. With PLM, short term purchases may be reduced.

C) Reduction in peak load would reduce maximum current through lines,

thereby reducing I2R losses. Thus technical losses would be reduced.

As per historical data, peak load in project area of Part I,Gurgaon is 1250

MW with daily 3 hours peak load ( timings:- 7 PM to 10 Pm ). Objective of

PLM in project area shall be to reduce peak load by about 10% i.e.

approx125 MW.

8.3 Other Benefits Apart from above functionalities, other activities shall have following

benefits:

(i) Power Quality Improvement: Reduction in losses, better

performance of equipment / appliances

(ii) Distribution Transformer Monitoring Units: Better knowledge of asset

(distribution transformer) utilization, reduction in outage, predictive

maintenance

8.4 Customer engagement plan

(iii) An outlay Rs. 1 crore has been kept aside for consumer awareness

program.

(iv) Consumer awareness workshops will be carried out in the different

RWA

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(v) Consumer engagement activity like painting competition for children

and Marathons for all ages of consumers including distribution of

promotional material like T-shirts, caps, etc.

(vi) Promotional material will be printed on the consumer bill

(vii) Promotional pamphlet shall be distributed,

(viii) Advertising will be done on TV, radio, new papers etc.

(ix) Peak Load Management System and consumer portal system is built

to contact consumers with the sms gateway & email system to get

frequent feedbacks and engage the consumers in energy

management, system monitoring etc.

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9 SCADA IMPLEMENTATION

Grid automation has helped distribution utilities across the world in

increasing their reliability, improving quality of power and optimum

utilization of their assets, resulting in higher customer satisfaction.

Automation decreases human intervention and helps utilities restore the

faulty equipment in minimum duration.

9.1 Componentsof Grid Automation Grid Automation has following components:

i. Software Modules installed in the control room

ii. Hardware installed in the control room

iii. Communication system like GPRS, CDMA, RF Mesh, OFC etc.

iv. Communication equipment i.e. RTU & FRTU

v. Motorized Switches for remote operation of grid

vi. Sensors such as MFTs, Weather Transducers etc.

9.2 Illustration of automated fault restoration by SCADA

Electrical system has been designed in a ring and if a fault occurs in any

part, the faulty portion is isolated and power is fed through alternate path.

The below mentioned diagram illustrates how the ring system works.

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If the closing and opening of load break switches is done manually, it takes

time and requires man power. But the same can be done remotely sitting in

the control room through grid automation system. In grid automation system

motorized load break switch/circuit breakers are installed which can be

controlled remotely through communication system and communication

equipment. Communication equipment are Remote Terminal Unit which

are microprocessor-controlled electronic device that interfaces objects in

the physical world to SCADA (supervisory control and data acquisition)

system by transmitting telemetry data to a master system, and by using

messages from the master supervisory system to control connected objects

. Communication system being used is optical fibre as it is most reliable and

has the potential to cater to future needs in terms of bandwidth. Moreover

laying optical fibre cable is very convenient, being laid over and above the

power cable, no separate digging or boring is required to lay optical fibre.

Sensors like MFTs, Weather transducers are used to collect information like

voltage, current, temperature, wind direction etc. and feed these to

communication equipment’s as mentioned above so that the

sameinformation can be taken to control room over communication system

like optical fibre cable. This is information is received by the front end

https://en.wikipedia.org/wiki/Microprocessor�

https://en.wikipedia.org/wiki/SCADA�

https://en.wikipedia.org/wiki/Telemetry�

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server of SCADA system which in turn shares it with various application

servers like SCADA , DMS , OMS , EMS servers etc. for their processing

and storing relevant information in database .

Supervisory Control and Data Acquisition (SCADA) shall provide a variety

of functions that can be grouped to provide core capabilities such as:

• Telemetry

• Monitoring and Alarming

• Controlling

9.3 Requirement of Software Applications with SCADA For optimum utilization of SCADA following software applications will be required:

9.3.1 Distribution Management System(DMS) Generally Distribution Management Systems include following

Sub_Systems over and above the SCADA application: -

I. Voltage/VAR regulation/control.

II. Load shed application.

III. Trouble call and outage management.

IV. Fault management (location/isolation) and System Restoration.

V. Load flow application.

VI. Network connectivity analysis/ Load calibration.

VII. Loss minimization/Loss calculation/Energy accounting.

VIII. Dynamic Network coloring.

IX. Load forecast.

X. Work order management.

XI. Geographical information system.

Voltage / VAR Control:The VVC function monitors the set of

telemetered voltage measurements associated with each VC-

controllable device. If the VC function detects a limit violation, it

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advises the corrective control actions to operator. VVC-controllable

devices are the set of transformers and capacitor banks selected by

the operator for VC control. Corrective controls include

incrementing/decrementing the transformer tap position, and

switching in/out a capacitor in a capacitor bank.

Load Shed Application

: -The load-shed application automates and

optimizes the process of selecting the best combination of switches to

open in order to shed the desired amount of load. The load shed

application recommends different possible combinations of switches

to open, in order to meet the requirement. The operator is presented

with various combinations of switching operations, which will result in

a total amount of load shed, which closely resembles the specified

total. The operator can then chose any of the recommended actions,

and execute them through a single action at the console. The

recommendation is based on an evaluation of load priorities and

current load levels.

Trouble call & Outage Management:-

I. Call handling

A trouble call and outage

management system shall be provided to handle telephone calls from

customers of the utility’s reporting electric service problems. Trouble

call and outage management system provides interactive voice

response and automatic call dispatch facility to track and report

problems, analyze and group problems by type and dispatch

problems individually or by groups to appropriate work crews for

resolution:

II. Call Analysis.

III. Task Assignment.

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IV. Outage Management and reporting

V. Fault and outage Management

VI. Based on the data organized by the call analysis function, an

additional consolidation of information shall be provided by the

TCOMS.

VII. A comprehensive view of the situation of the network shall be

presented to the dispatcher, allowing to quickly assessing the

nature and importance of the reported troubles.

VIII. The corresponding network trouble tickets shall be assigned to

repair crews, and the progress of the work properly managed,

including the monitoring of partial restorations.

Fault Management (location/isolation) and system Restoration

The Fault Management & System Restoration function provides

assistance to the DMS dispatcher for detection, localization, isolation

and restoration of the distribution system. In case of permanent fault

in the Distribution network, the function proposes switching plans to

restore the supply in the healthy parts of the faulty feeder. The

function shall also be usable and compute switching plans to assist in

the cases of reconfiguration of the network required by maintenance

operations or partial load transfer of an overloaded feeder to the

neighboring feeders.

: -

Load Flow Application: -A power distribution network normally

consists of a large number of devices; a correspondingly large

number of measurements are thus needed to describe its state. In

most cases, however, relatively small portions of the electrical

quantities at network locations are actually measured. The Load flow

application provides values for those electrical quantities at network

location where measurements are not available.

These values are useful both in terms of providing a more

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complete view of the network to the operator in real-time, and as the

basis for the remaining DMS software for which the load flow results

serve as inputs.

Network Connectivity Analysis

The NCA function determines the topology of the distribution network

based on the physical connectivity of devices in the network and the

status of connecting devices such as switches. The electrical status

of each device in the network can be presented dynamically to the

operator on one-line displays. The dynamic display rendering of

electrical status provides an indication of energized/de-energized

state, and whether the device forms part of a loop or a parallel path.

: - The network connectivity analysis

function forms the basis of the analysis/decision/action tools available

to operators. Aside from providing live/dead status information to the

operator in real-time, the results of the NCA function serve as inputs

to virtually every other application in the DMS software package.

Loss Minimization/Loss calculation/energy accounting

The loss minimization via feeder reconfiguration study application

identifies an alternative network topology, which, while meeting the

same nodal power demands, incurs smaller distribution losses. To

this end, the function recommends a series of switching operations,

each consisting of opening one switch and closing another switch, in

order to transfer load from one feeder to another.

: -The loss

minimization optimization study functions provide recommendations,

which may allow operators to reduce overall system losses, thereby

reducing operating costs. Also, the loss minimization

recommendations would result in improved quality of service and

increased reliability.

Dynamic Network coloring: - The Dynamic Network Coloring shall

enable the DMS operator to visualize the operational conditions

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present in the distribution network. Different types of coloring shall be

available.

I. Automatic coloring

II. On-demand coloring.

Work orders Management

I. The description of the elementary operations to be performed.

: - Work Orders Management (WOM) shall

provide a flexible way to automate the management of job forms

describing the construction and maintenance works on the electrical

network and support the job sheet description and the full life cycle of

the job form. These job forms shall consists of the following

information:

II. The life cycle of the job forms, from their creation through

approval, execution and eventually archival of the form.

III. The necessary information to the operator pertaining to the job

being done such as electrical section getting affected, time

expected to carry out the job and operations not permitted to

perform during this period.

Geographical Information System

: -Geographical Information includes

the network diagram superimposed on geographically map of the

area. The breakers and switch status (on/off/lock) are indicated.

Feeder condition (Lie/dead/Maintenance) is also displayed on the

screen.

9.3.2 Outage Management System

The Outage Management (OM) shall be a collection of functions, tools, and

procedures, which an operator or dispatcher uses to manage the detection,

location, isolation, correction, and restoration of faults, which occur

unexpectedly on the utility electric network.

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1. OM shall also be used to facilitate the preparation and resolution of

outages, which are planned for the network. OM processes shall be

used to expedite the execution of the tasks associated with the

handling of outages that affect the network and provide support to

operators at all stages of the outage life cycle starting from events

such as the reception of a trouble call or a SCADA indication of an

outage, until power is restored to all customers.OMS processes shall

further be used to resolve the outage whether the outage is at the

level of a single distribution transformer providing power to one or few

energy consumers or the level of a primary substation providing

power to many energy consumers.

2. All operations, authorizations, and comments, which occur in these

processes shall be documented and collected in outage records. It

shall be possible that this information is made available to external

sites for further statistical analysis and processing.

3. OM shall provide the automatic processing of an outage record used

to monitor changes in the network and have an internal interface to

Crew Management, Switching Procedure Management, and Trouble

Call Management.

4. Data communication to external applications shall be enabled through

web service adapters in the framework of a Service Oriented

Architecture.

9.3.3 Applications at Smart Grid Control Centre:

The Smart Grid Control Centre will have to be fully equipped to discharge

its responsibility as defined in Smart Grid Code & all applicable codes. The

functional requirements will need following tools for operator to optimally

meet challenges of operating a modern SLDC/SSCC.

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(a) Load Forecast (b) Outage Scheduler (c) State Estimation (SE) (d) Contingency Analysis (CA) (e) Optimal Power Flow (OPF) (f) Transmission capacity monitoring (TCM) (g) Operation monitor

9.3.4 Switching Procedure Management

Switching Procedure Management (SPM) of the Network Control Center

System shall allow the operator to create, edit, select, sort, print, execute,

and store switching procedures. It shall be possible to create entries in a

switching procedure manually by recording the operator's actions in a

simulation mode, by modifying an existing procedure, by recording the

operator's actions in real-time mode, or automatically by applications, such

as, Distribution Network Applications.

1. The SPM capabilities shall enable preparing, studying and executing

clearance operations. SPM shall also be used to execute switching

operations to alleviate fault conditions and to restore power following

a fault, as well as for the optimization of the network operation.

Switching Procedure Management shall provide management

capabilities via summary displays and easy-to-use menus.

2. Load shedding shall enable an operator to shed or restore a list of

load control elements, shed or restore to a specified MW load

curtailment, shed or restore a percentage of the total available load in

a list, or rotate shedding through a list of load control elements.

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9.4 Benefits of Implementation of SCADA & Software Applications

Combined benefits of implementation of SCADA along with supporting software applications illustrated above can be summarized under following main heads:

9.4.1 Leading functionality SCADA functionality is based on advanced and proven algorithms, for

instance for fault location, as well as for restoration and network

reconfiguration. The traditional SCADA functionality, such as on-line

network monitoring data, is complemented with an advanced DMS network

database. This enables new real-time applications for improved network

monitoring and outage management. Fault location along the feeder can be

determined instantaneously and exact fault location can be presented on a

geographical map.

9.4.2 Operation and informative presentation of the network Using SCADA, the operator can monitor the network state and related

measurements, and then perform the control actions needed. Versatile

process displays, lists and application tools for network tracing, locating

components and reporting provide the necessary information for different

users. Dynamic line coloring delivers information about topological

connectivity, powered/un-powered network sections and about overloaded

lines and voltage drops. The entire network can be viewed on detailed

geographical maps in raster and vector formats, as well as in a schematic

diagram. Zooming, panning and de-cluttering enable a clear overview and

allow users to focus on a specific area to obtain detailed information. The

functions are at hand via process displays, maps and schematic network

views. In geographical views, several map layers can be used to provide

the details needed. The system automatically selects the correct map layer

in accordance with the current zoom level. Network effects caused by

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distributed generation can be analyzed and corrective actions planned and

simulated.

This can already be done in the network planning phase or alternatively

during the real-time operation. Also short-term forecasts of generation can

be used so that operational changes and controls for load or generation

can be planned and informed in advance.

SCADA extends traditional SCADA functionalities by providing

geographically based network views and advanced distribution

management functions over the entire distribution network.

9.4.3 Dependable Operational Safety SCADA prevents simultaneous operation of primary equipment. It reserves

the device, and verifies whether the selected object can be operated,

before executing the command. Additionally, interlocking schemes prevent

dangerous operations that might otherwise damage primary equipment.

Only authorized users can override interlocking and other locked

operations. Common safety procedures require that any mechanical or

electrical equipment can be locked out and tagged out before being worked

on. Responsible for meeting safety requirements, rules and regulations,

SCADA includes a lock-out/tag-out function. The lock-out/tag-out function

ensures that control of objects in the application or other operations are

properly secured prior to and during, for example, maintenance or servicing

work. An application object in tag-out state can easily be identified on the

HMI by the intuitive tag-out display symbol. SCADA’s dynamic network

coloring function provides the operator with quick access to information

about the powered, un-powered and earthed parts of the network.Alarming

objects are also visualized. The network coloring, combined with object

control simulation of SCADA, ensure the safe and correct operation of our

electrical network.

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9.4.4 Intelligent switch order management The switch order management function supports planning, simulation,

execution and reporting of scheduled maintenance outage operations. The

intelligent algorithms automatically optimize the switching sequence to

minimize the number of affected customers. Through its operation planning

functionality, SCADA allows both automatic and manual switch orders to

open and close switching devices in the distribution network or performing

other actions during the outage. Switch order documents with user-defined

actions can be created based on company-specific Microsoft Word

templates. The switching planning takes the technical constraints of the

network into account, such as voltage drop and load level for each line

section. Furthermore, it eliminates damage to primary equipment and the

network during maintenance outages by ensuring correct relay protection

operation at all times.With the world map view of SCADA, detailed

consumer information is just a few clicks away.

With the help of SCADA , detailed consumer information is available instantaneously

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9.4.5 Reduction in Outage duration The advanced distribution management functionality reduces outage time

from hours to minutes. The system retrieves registered data about fault

currents or impedance from protection and control IEDs. It also utilizes data

provided by Feeder Terminal Units (FTU) and fault indicators. This data

together with the network model is used to calculate the fault location,

which is instantaneously shown in the network view.Then, restoration

support provides the operator with a list of recommended actions, such as

reconfiguration of the entire network to minimize the outage area. This

allows for fault isolation and fast and safe network restoration. Restoration

can also be executed completely automatically. In a fault situation, the

GPS-based field crew management enables the operator to quickly find the

nearest service crew.With the help of the integrated geographical map, the

operator can guide the crew to the fault location, where necessary manual

switching operations can be performed to isolate the fault. Or the crew can

access the system via mobile communications or hand-held computers,

which further simplifies the entire process. With the advanced fault

management functionality, you can provide excellent service to your

customers. SCADA system helps to locate the customer calling in and

allows to immediately informing the customer about the fault and its

expected repair time. Integration of an Advanced Metering Infrastructure

(AMI) system into SCADA offers the possibility to use the communication

and smart meter infrastructure created, mainly for energy metering, to also

remotely monitor the low voltage networks. This function enables

spontaneous alarms to be received regarding network faults and voltage

violations. It can also read measurement values from the energy meters.

Alarms from several customer meters can be combined and faults in the

low-voltage network can be located. SCADA also features a Trouble Call

Management function that stores and presents any type of customer

contact. The function provides also customers with information about

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network disturbances and collects information about the faults, such as the

nature and location of the fault.

9.4.6 Fast and efficient reporting of operational statistics and outages Outage reports covering faults, maintenance outages and also reclosing

trips. Based on the data stored in a relational database, various statistics

and indices, such as SAIDI, SAIFI, CAIDI and CAIFI *) can be created. Both

SCADA and company-specific reporting tools can be used. The detailed

storage of outage information even allows the retrieval of customer-specific

outage histories, which can significantly improve customer service.

Individual customer outage reports can be automatically generated if

requested by the authorities. To achieve a complete view of the network

condition and service quality for action planning, these reports(including, for

example, frequent fault locations and device failures) can be integrated into

the company’s business system (ERP) or utilized in a data warehouse

implementation. Measurement reports those present currents, voltages and

active and reactive power in both numerical and graphical formats. The

reports can contain, for instance, five-minute or hourly average values.

Energy reports in both numerical and graphical formats containing active

and reactive energy data with yearly, monthly, weekly, daily and hourly

statistics based on three-minute average values. Customized reports are

easily produced using the flexible Historian that can store all process data

for long periods and refine the data into meaningful information. This gives

a clear view of the situation in the primary process and allows for optimized

utilization of the power and primary equipment. Reports and statistics are

easily produced. The information is visualized in the form of various graphs,

trends and numerical reports. The numerical reports can utilize embedded

Microsoft Excel which provides commonly known tools for further data

refinement.

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9.5 Implementation of SCADA in project area: Architecture & BOQ To achieve the objectives of Smart Grid SCADA control centre, the

requisite SCADA system will be installed in the project area which will

supervise and control the 11 kV distribution network in the project area.

This SCADA system will carry out the following functions at Distribution

level.

i. Resource management for optimum utilization capable to automate

transmission and distribution system with proven efficiency and

reliability based on the steadfast digital technologies. The centralize

station to facilitate energy auditing , preparation of energy accounts

and losses up to DT level having sync with billing and outage

management & response time.

ii. The system architecture will facilitate crew management system,

maintenance management system, power system network

applications, load balancing & network management, distribution loss

minimization, and power quality monitoring & reliability assessment.

iii. The proposed central station to provide higher level of automation at

substation to elevate reliability of power system network and

unmanned operation of substations with a coordinated control, is

required to be established the state of art available technologies,

features, facilities in hardware and software which could at least

deliver and handle SCADA

iv. ADMS/OMS/GIS/CIS/Asset management/weatherforecasting/Load

forecasting/resource management/Visual Monitoring System/Fire

management system/Access control system/Building Management

system , integration of renewable energies and real time two way

communication from source to sink to ensure resilient 24x7 power to

the consumers.

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9.5.1 Activities to be performed in Distribution System:

i. Remote operation of distribution transformers

ii. Automatic detection and isolation of faulty area using FPI

iii. Automatic restoration of supply by backfeeding of feeder from

alternate source after isolation of faulty portion

iv. Remote monitoring of varies parameters of distribution transformers

v. Due to availability of data in database , the SAIDI , SAIFI and CAIFI

can be created and monitored for improved power quality

vi. Load forecasting of area

vii. Health monitoring of all the breakers installed on 11 kV network

viii. To help in Short circuit current calculation of the distribution network

9.5.2 Common SCADA Control centre

One SCADA control room for distribution system has been proposed at 220

kV S/Stn, Sector 52, Gurgaon and back up control centre is proposed to be

built in Hisar town. In the present scenario, it will handle the 11 kV network

of the entire project area (Part I) i.e. sector 1 to 57 of Gurgaon. In future this

SCADA control room will control complete Gurgaon from sector 1 to sector

115 having an estimated no. of nearly 6 lacs of consumers.

9.5.3 Communication Network

For remote operation of distribution transformers and fault identification and

rectification at 11 kV; approx. 3000 no. RMU of various specifications have

been proposed. The RMU’s are SCADA compatible (i.e. motorized RMU’s

with FRTU’s and FPI). The data will be collected by FRTU’s at each RMU’s

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and same will be transmitted to nearby 66 kV feeding S/Stn through optical

fiber. At the substation, the data will be collected and merged at FODP

installed at each substation. From substation to SCADA control room; the

data will be transmitted / transported through optical fiber and will be

collected at SCADA control by Front End Server installed in SCADA control

room. This data will be shared with different application servers like

SCADA,DMS,OMSetc.

9.5.4 Field Equipments

The following equipment are required in field for distribution purpose :

RMU ( Ring Main Units)

Outdoor type 11 KV SF6 type non extensible and motorized 5 way smart Ring Main Unit (RMU) complete with two VCB and three LBS with FRTU and FPI as per IS

Nos. 100

Outdoor type11 KV SF6 type extensible and motorized 4 way smart Ring Main Unit (RMU) complete with two VCB and two LBS with FRTU and FPI as per IS

Nos. 500

Outdoor type 11 KV SF6 type extensible and motorized 3 way smart Ring Main Unit (RMU) complete with one VCB and two LBS with FRTU and FPI as per IS

Nos. 2000

Outdoor type 11 KV SF6 type extensible and motorized 3 way smart Ring Main Unit (RMU) complete with all three VCB and with FRTU and FPI as per IS

Nos. 50

Outdoor type 11 KV SF6 type extensible and motorized one way smart Ring Main Unit (RMU) complete with LB and with FPI as per IS

Nos. 300

Outdoor type 11 KV SF6 type extensible and motorized one way smart Ring Main Unit (RMU) complete with VCB and FPI as per IS

Nos. 50

Optical Fiber

Un- Armoured Optical Fiber (48 Fibers) along with the all accessories connectors, switches etc.

KM 1974

124

Armoured Optical Fiber (48 Fibers) along with the all accessories connectors, switches etc.

KM 846

PLB-HDPE (Permanently Lubricated High Density Poly Ethylene) pipe 40 mm. dia pipe for laying optical Fiber Cable.

KM 2820

9.5.5 Components of SCADA Control room The following equipment are required in the SCADA Control Room :

Server/Workstation Hardware Unit MCC BCC TotalQty Reason for Incorporating

SCADA,ADMS,OMS Server Nos. 2 2 4 Application Server

for SCADA, DMS,OMS

DMS Simulation Server Nos. 2 0 2 Training of operators

DMS Realtime Historian Server Nos. 2 2 4 History parameters of all equipment

FEP,Communication,ICCP Integration Server Nos. 2 2 4 Communication

server

ISR Server {Data Server} Nos. 2 2 4 Data Retrieval/Archival

NMS Server Nos. 2 2 4

Network Management for

monitoring health of communication

system

Developmental Server Nos. 3 3 6 Coding requirement

Web/Directory Server Nos. 2 2 4 Interface with

devices which need data on internet

Asset Management Server Nos. 2 2 4 Life Cycle

management of Equipment

Visual Monitoring Server Nos. 4 4 8 Physical

Surveillance of Substations

Weather Forecast System Nos. 2 2 2 For weather

forecasting for Load forecasting

LV Automation Monitoring (Non-Technical Losses) Server Nos. 4 4 8 Calculation of

Losses LED based Video Projection system with 2X3 Module configuration with each module at least 67" diagonal with common projector

Set 1 1 2 For having single screen view of whole system

125

Hardware for BMS Lot 1 1 2 Building HVAC ,

Accees control and related hardware

Sensors Nos. 1000 MFTs

Cameras for VMS Lot 50 Physical Survilance of Substations

SCADA software Lot 1 1 2

Software of ADMS ISR Software Lot 1 1 2 DMS software Lot 1 1 2 OMS Software (MV & LV System) Lot 1 1 2

DTS software Lot 1 1 2 Software for Training of operators

Developmental software Lot 1 1 2 Software for Bug fixing and other

coding requirement

Network Management Software Lot 1 1 2

Network Management for

monitoring health of communication

system WEB/Network security software (Included in IT Package) Lot 1 1 2 For Cyber security

purposes

RDBMS package (Included in ISR) Lot 1 1 2

Database Management

Software GIS Adaptor/Engine for importing data from GIS system under IT system

Lot 1 1 2 Importing data from GIS module

Field Client / Web Client Licences for ADMS System Lot 15

Software for Interface with

devices which need data on internet

Inbuilt Web Call Centre for Vip Consumers (Upto 1 Lakh) Lot 1 1 2

Call centre module for grievance redressal of consumers

Asset Management Lot 1 1 2 Software for Life

Cycle management of Equipments

AVTL (Automatic Vehicle Tracking System) Lot 1 1 2 Crew tracking

software Renewable Integration & Weather Forecasting

Lot 1 1 2 Software For

weather forecasting for Load forecasting

Building Management system + Access Control + Fire Management System

Lot 1 1 2 Software for Life


UPS of Control Centre (20 kVA Redundant UPS) Lot 1 1 2 Uninterrupted power

supply

126

All the 11 kV VCB’s at existing 66 kV S/Stns in the project area will be replaced/retrofitted to make them SCADA compatible Breakers/VCB’s.

Visual Monitoring Software Lot 1 1 1 Software for Life


127

10 NETWORK UPGRADATION & STRENGTHENING

10.1 Proposed Network Up-gradation / Strengthening Initiatives by DHBVN

As per MoM dated 08.10.2015, it was proposed by committee of engineers

that the entire Distribution system in project area may be converted to 33

KV level. However, during planning phase of Project, various discussions

were carried out and in meeting dated 06.02.16 and 11.02.16, following

major decisions were taken:

It was proposed that hybrid system of 33 kV and 11 kV as

Primary distribution voltage may not be introduced in Phase 1 of

Project

The supply may be distributed at 11 KV level and 66/11 KV

substations may be constructed at load centres of Project area

instead of 33/11 KV Sub-stations.

Following attributes are proposed in project area of Part I i.e. sectors from 1

to 57, for electrical distribution infrastructure Upgradation/Strengthening:

• Switch over from overhead HT system to underground system based

on feasibility, wherever possible, by laying cables through trenchless boring

or otherwise by simple digging, as the case may be. Where the laying of

underground cables will not be possible, an overhead system on mono-

poles will be erected.It will address the problems of:

Right of way from existing Substations due to congestion for laying of

new feeders

High down-time of 11 KV feeders due to existence of multiple feeders

on common poles

• 100% redundancy level will be created at the distribution level (at 11

KV feeder level)

128

• Ring Main Units (RMUs) will be installed on different sections to

ensure uninterrupted power supply

• Laying of LT underground network/ erection of LT Aerial bunched

feeders in theft prone areas based on feasibility

• Up gradation of overloaded Distribution transformers capacity and

augmentation of Low tension network

• Operation staff will be equipped with latest state-of-art maintenance

equipment to carry out inspections

• After laying of the new up-graded 11 kV system with 100%

redundancy, complete system will be operated and maintained by

DHBVN staff

129

10.1.1 Layout of Existing 11 KV Radial feeders

Electrical S/STN-1

Electrical S/STN-3

Electrical S/STN-2

130

10.1.2 Layout of proposed 11 KV Ring Main System

E/SSTN-1

E/SSTN-3

E/SSTN-2

131

LEGENDS

220/66 KV SUBSTATION

11 KV UNDERGROUND/OH CIRCUIT

PROPOSED 11 KV UG/OH CKT FOR 11 KV RING MAIN

LT FEEDER PILLAR FOR O/G LT feeders

4 WAY/3 WAY RING MAIN UNIT

11KV/0.433 KV DISTRIBUTION TRANSFORMER

E/SSTN

132

10.2 Proposed sequence of execution of various phases under Part-I of Project

For the ease of execution and better project management, Distribution up

gradation/augmentation in sectors from 1 to 57 will be carried out in

different phases as proposed below:

Phase Area Description

I Area falling under Sector 14,17,24(DLF-III),30,31,32A, 32,39,40, 41,Part of sec-27,27,43(Sushant Lok-I) & area on both sides of Sohna Road

II Area falling under Sector 25A,25,26,26A,27,28,42 &43 (Under DLF city Subdivision)

III Area falling under Sector 3A,5,6,11,11A,12,12A,15-I & 15-II (Under IDC Subdivision)

IV Area falling under Sector 18,19,20, 1,2,21,22,23,23A (Under Maruti Subdivision)

V Area falling under Sector 10, 10A,36,37,37A,37B ,37C &37D(Under Kadipur Subdivision)

VI Area falling under Sector 44,45,46,51,52, 53,54,55,56,57&58 (Under South City Subdivision)

VII Area falling under Sector 33,34,35,38, 47,48,49 &50 (Under Sohna Road Subdivision)

VIII Area falling under Sector 4,7,8,9,9A & 9B (Under New Colony Subdivision)

10.3 Existing and proposed System study for Sample area

In order to illustrate the shortcomings of existing 11 kV network ,improved reliability with proposed network and architecture to be adopted for 8 phases of the project , a sample study of Sushant Lok Phase-1 area to be covered under Phase 1 has been illustrated:

133

10.3.1 Existing loading details of 11 kV feeders

FEEDER WISE DATA MAXIMUM DEMAND FROM JAN.-2016 TO JUNE-2016 IN R/O SUSHANT LOK-1 AREA UNDER DLF CITY S/DIV. DHBVN, GURGAON

Month wise,S/Stn.wise T/Former wise,feeder wise Maximum Demand in Amps from 1/2016 to 06/2016.

66 KV S/Stn. Sec-52 Area being fed Jan-16 Feb-16 Apr-16 May-16 Jun-16 REMARKS

25/31.5 MVA T-I 708 620 1296 1212 1542 25/31.5 MVA T-II 672 642 1296 1050 1020

220/66 KV 100MVA T-III T/F 1128 1008 1248 1530 1560

1 11 kV WELLINGTON S LOK 1 140 120 220 250 250 2 11KV SUSHANT LOK- I S LOK 1 180 180 200 280 250 3 11 kV SUSHANT LOK -II S LOK 1 290 130 230 270 260 66 KV S/Stn. Sec-28 25/31.5 MVA T-I 612 582 798 930 942 25/31.5 MVA T-II 660 660 738 990 990

12.5/16 MVA T-III 120 102 120 120 150 RAPID

METRO 4 S.Lok-III S LOK 1 130 130 150 240 230 66 KV S/Stn. Sec-43 25/31.5 MVA T-1 630 678 0 0 408 25/31.5 MVA T-2 342 348 1368 1632 5 Sushant Lok-II S LOK 1 50 50 150 140

S/LOK AREA PEAK L

(IN A) LOAD (IN

MVA) PRESENT LOAD 1190 23

ULTIMATE LOAD 41

10.3.2 Load flow analysis of existing 11 kV feeder

Load flow analysis of existing 11 kV feeder is placed as Annexure- E.

10.3.3 Ultimate Load projection of area under S.Lok Phase-1 up to Yr. 2031

Load projections for area under Sushant Lok Phase-1 up to year 2031 have been arrived at on the basis of existing DHBVN load norms for

134

electrification of area developed by HUDA/colonizers/SEZs etc. and is tabled below:

SUSHANT LOK-1

TYPE AREA (SQ.MT.)

ULTIMATE LOAD PER

PLOT

Nos Total Load (In KVA)

I 51.25 6 1018 2715

II 180 16 1304 9273

IIB 144 12 23 122.5

IIC 300 16 38 270

IID 220 20 6 53

III 250 20 1422 12640

IIIA 300 25 13 144

IV 350 25 598 6644.5

IVA 300.1 25 56 622

V 420 30 347 4626.5

VA 348 25 70 777.5

VI 680 40 113 2009

VIA 616 30 16 213

VII 810 40 56 995.5

VII'' 675 30 11 146.5

Total 41252

10.3.4 Load flow analysis of Proposed network

Single line diagram and Load flow analysis of proposed 11 kV network for Sushant Lok phase-1 area is placed as Annexure-F.

135

10.3.5 Results of load flow analysis

The existing network in the area is a mixture of underground XLPE cable as

well as aerial bunched cable and ASCR 80sqmm conductor. All the feeders

are radial in nature which cater to the load demand in that particular area

only. It is proposed to convert all the overhead feeders into underground

feeders with XLPE cables of sizes 400sqmm, 300sqmm or 120sqmm. It is

also proposed to introduce RMUs in the system. RMUs shall be installed

along with all DTs of ratings 400 kVA and above, HT connections and

looping points with other feeders etc.

All the above data including feeder type, feeder lengths, feeder parameters,

peak loading of DT, demand factor, power factor, etc was imported to PSS

SINCAL software and simulations were carried out.

In the existing scenario, it was found out that some of the 11kV feeders

were overloaded upto 186.48% of rated capacity. Also, in case of fault in

any feeder, it was impossible to re-route the power supply from alternate

feeders.

In the proposed situation, introduction of RMUs and dual redundant link

with each feeder has improved the reliability of the system. Consequently in

the proposed network, the max loading in any feeder was limited to 71.47%

of its rating. There was no voltage regulation related issues here. Feeder to

feeder interconnections is reliable enough to feed power in case of an

outage.

10.4 Load forecasting methods for Gurugram Gurgaon City is one of the cosmopolitan city in the vicinity of Delhi, and

witness exponential growth in last few year with its electrical demand

growing at the rate of 12-13%, For development of Smart City in Gurgaon,

136

one of the most challenging task is accurate load forecasting in scientific

and accurate manner. Following methods of load forecasting were

considered:

10.4.1 Similar-day Approach This approach is based on searching historical data for days within one,

two, or three years with similar characteristics to the forecast day. Similar

characteristics include weather, day of the week, and the date. The load of

a similar day is considered as a forecast. Instead of a single similar day

load, the forecast can be a linear combination or regression procedure that

can include several similar days. The trend coefficients can be used for

similar days in the previous years.

10.4.2 Regression Methods. Regression is the one of most widely used statistical techniques. For

electric load forecasting regression methods are usually used to model the

relationship of load consumption and other factors such as weather, day

type, and customer class.

10.4.3 Time Series. Time series methods are based on the assumption that the data have an

internal structure, such as autocorrelation, trend, or seasonal variation.

Time series forecasting methods detect and explore such a structure

10.4.4 Neural Networks. The use of artificial neural networks (ANN or simply NN) has been a widely

studied electric load forecasting technique since 1990 (see [28]). Neural

networks are essentially non-linear circuits that have the demonstrated

capability to do non-linear curve fitting.

10.4.5 Expert Systems. Rule based forecasting makes use of rules, which are often heuristic in

nature, to do accurate forecasting. Expert systems, incorporates rules and

137

procedures used by human experts in the field of interest into software that

is then able to automatically make forecasts without human assistance.

10.4.6 Fuzzy Logic

10.4.7 Support Vector Machines

Based on the available resources in hand and taking into account Memo

No. Ch-9/GM/Comml./ R-16/28/2004/F-11 Dated 27/1/2014 of DHBVN for

Approval of Electrification Plan in the colonies / Multi-storied Buildings

/Group housing societies developed by HUDA / HSIIDC /Private Colonizers

/ SEZ., time series method (past load growth method) was considered.In

that method, data of past five year consumer wise demand was considered,

structured data of future plan was collected from the Huda, economic

growth in the past five year and change in consumption pattern of

consumer vis a vis economic growth was studied and based on above

approach load up to 2022 was forecasted, which resulted in a growth rate

of 10% per annum.

10.5 Proposed Network Up-gradation/Strengthening Initiatives by HVPN

Based on studies, Transmission system strengthening was evolved which

broadly includes following:

• Establishment of new 220 kV substation (GIS) to cater to requirement

of new demand centers

• 220 kV Multi circuit Transmission line (High capacity conductor)

(Overhead/Cables)

• Formation of 220 kV Transmission ring beneath planned 400 kV ring

138

• Augmentation of Transformation capacity on existing/under

construction/HVPN planned Substation at 220/66 kV level

Proposed 400 kV Transmission Ring around Gurgaon

Considering establishment of new 400/220kV substations at Farukh Nagar

(HVPN), Sohna Road (ISTS) &Kadarpur (ISTS), it is proposed that future

load may be served

139

From these load centers based EHV substations so as to relieve

loading of 400kV Daultabad and Gurgaon (PG)/Sec-72 Sub-

stations. Following transmission system is envisaged to come up

in near future at Intra/Inter-state level:

400/220kV substations (3630 MVA)

• Farukh Nagar (2x315 MVA) (HVPN)

• Sohna Road (2x500 MVA) (ISTS)

• Kadarpur (2x500 MVA) (ISTS)

Present Transmission capacity of HVPN alongwith future expansion plan

has been discussed in detail under Chapter of Transmission

140

11 COST ESTIMATES & BENEFITS

Estimated cost of implementation of features of Smart Grid project is Rs.

1608Cr . Cost of SCADA implementation has been taken as one time cost

and includes fixed cost for setup of control room and other system

applications.

11.1 Estimated Cost of Project (Sectors 1 to 57) For detailed estimated cost of Project refer Chapter “Project estimated cost”.

11.2 Benefits Smart Grid project is being done as an initiative to embed new technologies

in distribution system in small scale and successful implementation would

draw the way forward for large scale implementation. Therefore for such a

project finding economic viability and feasibility would be prejudice as

qualitative benefits are of paramount importance. Large scale

implementation in future may only prove economies of operation. The main

benefits of the project are as under:

• 24x7 power supply to all consumers.

• Make Gurgaon Diesel Generator Free.

• Reduce AT&C Losses.

• Improve reliability of power by reduction of outage rate and duration.

• Ensure quality power supply by reduction of harmonics

11.3 Cost Benefit Analysis

11.3.1 Benefit of Implementation of AMI in sectors 1 to 57 Gurgaon

Project area Part I Gurgaon is expected to achieve following benefit as the

outcome of distribution strengthening and smart grid.

141

11.3.1.1 Reduction of AT&C losses

• AT&C losses of project area is around 9.47 %

• Total Energy input to project area is 3988 MU in year 2015-16 time

duration.

• Total billed energy is 3684 MU in year 2015-16 time duration billing

efficiency (92.38%).

• After smart grid intervention billing efficiency expected to increase up

to 95% and total billed energy will be 3788 MU

• Additional energy billed is 104 MU.

• Revenue saving out of above saving of 104 MU shall be Rs 82.89 Cr.

when the average sale of energy is Rs. 7.97 /unit (ROR on

Assessment and Unit received)

11.3.1.2 Reduction in average cost of billing At present Average cost of billing is Rs. 300/per year/consumer by aiming

70% reduction in the billing cost, cost of billing shall be reduced by Rs. 210/

per year/per consumer hence total saving for 224363 Nos. of consumers is

Rs. 4.71 Cr.

11.3.2 Peak Load Management Reduction in peak demand

• The peak demand is 1388 MVA. Power factor is 0.9. Average Peak

load time is one hour per day on average basis.

• During the peak time consumption is 1250000 Units.

• Reducing the peak demand to 1249 MVA, the peak consumption will

reduced to 1124280 Units, saving 125720 U

• For 125720 Units, differential UI charges for peak and non-peak is

Rs. 5 /unit hence saving in revenue by shifting peak demand is Rs.

22.94 Cr (365 days for one hour).

142

Benefit from Peak Load Management would require regulatory provisions

such as Time of Day (TOD) tariff.

11.3.3 Outage Management System Reduction in outages:

Above mentioned OMS/SCADA scheme shall be installed in 11kVnetwork

of Gurgaon. It is estimated that present tripping rate of approx. 2395

tripping per year may be reduced to Nil tripping per year. Table below

shows the benefits due to reduction in lines trippings after implementation

of OMS.

Table : End scenario of line tripping after OMS

Description Present

status

After Smart Grid

and System

strengthening

Total no of line Outages in the year for 479 Nos.

of feeders 2395 0

Average time taken for restoration (Hrs) 3 0

Average cost of restoration per outage (Rs lac) 0.1 0.1

Total Cost of restoration (Crore) 2.395 0

Benefits due to reduction in restoration cost (Rs.

Cr) 2.395

Average Energy Loss per outage (MU) (2000

unit/hr) 0.0048 0

Total energy loss ( MU) 14.37 0

Increase in Energy Sales (MU) - 14.37

Benefits due to Higher energy sales assuming

profit of Rs. 3.44 per unit(ROR on Ass./UB - Avg.

cost of supply) (Rs.Cr) - 4.94

143

Benefits by reducing number of outages and outage durations would be

following:

• With the proposed reduction in line outages from 2395 to Nil, the total

saving in restoration cost would be Rs. 2.395 Cr/year

• Due to higher energy sales because of reduced failures/ increase

availability, the increase in gross profit for the utility would be Rs. 4.94

Cr/ year

DTMUs

For monitoring oil level, temperature & loading of distribution transformers,

monitoring units shall be installed which shall be helpful in reducing number

of outages, outage duration & restoration time. Also system strengthening

shall also reduce overloading and thus failure of equipment, reducing

outage time. By increasing reliability and reducing outage of DTs, there will

be reduction in No. of transformers under repair also, which will increase

the availability of transformer in store as well. Presently, failure rate of

transformers is at 3.58%, which means 143 distribution transformers have

failed against total strength of 3991 nos. in FY 2014-15. By virtue of

transformer monitoring units this failure rate may be brought to 1% level.

Table below depicts benefits after reduction of distribution transformer

failures due to OMS implementation.

Table : End scenario of DT Failures after OMS

Description Before System Strengthening

After System Strengthening

Total No. of DTs 3991

Percentage of DT failure (2015-16)(Annual rate) 3.58% 1.00% Approx. no. of failures per year

143 Total time taken for restoration per outage/DT failure(Hr) 24

144

Average cost of restoration per outage(Rs in Lac) 0.516 Cost of restoration(Rs Lacs.)

73.788 Benefit due to reduction in restoration cost(Rs Lacs) A 53.19 Average Energy loss per outage(MU)(100 Unit/hr) 0.0024 Total energy loss(MU)

0.3432 Increase in Energy Sales(MU)

0.247416 Benefit due to higher energy sales assuming benefit of Rs 3.44 per unit(Rs Lacs) B 8.51 Total Annual Benefit (In Rs Lacs.) (A+B) 61.71

Benefits by reduction in number of outages & outage time of distribution

transformers shall be as under:

• With the proposed reduction in DT outages the total saving in

restoration cost would be Rs. 0.53cr /year

• Higher energy sold through the reduced failures/ increase availability

the increase in gross profit for the utility would be Rs 0.085 Cr/ year.

Thus the total benefit to the utility due to outage management system

(benefits from improved scenarios of line trippings& DT failures) would be

Rs.7.95 Cr per Year. Outage Management System benefits can be

achieved subject to deployment of mobile and well equipped maintenance

crew. Also by increasing reliability in supply, a lot of value comes to society

by means of uninterrupted facilities in public services & social causes

whose cost cannot be written in black & white.

11.3.4 Benefit due to due to augmentation of undersize LT conductor Presently LT conductor of LT feeders of various capacity DTs in sectors 1

to 57 has rendered undersize due to increase in load growth over the

years.Also, ACSR O/H has become worn out and old due to ageing

145

thereby leading to higher technical losses. Augmentation of LT ACSR

undersize conductor to higher size conductor technical losses will reduce

as illustrated by table below:

Table : End scenario after augmentation of LT size conductor

Description Distribution Transformer Capacity wise (In No.s)

100 200 315 400 500 630 990 No. of Distribution Transformers from sector 1 to 57 1452 2159 8 110 9 28 14 Average span length (In M) 30 Average No. of Spans/DT 4 5 6 6 8 10 Average LT feeder length (in M)(L) 120 150 180 180 240 300 Phase current at Avg DT loading(x) cond.(I) 92 184 290 368 460 580 912 Total I*I*R loss for existing 50 mm2 ACSR (in W)(3*I*I*r*L*N)(u) 16031474 184197 4900775 626520 4126007 6367944 Total I*I*R loss for aug. 100 mm2 ACSR (in W)(3*I*I*r*L*N)(u) 8102848 93099 2477017 316664 2085423 3218574 Total Unit lost per hour due to 50 mm2 ACSR (U50=u/1000) 16031.47 184.20 4900.77 626.52 4126.01 6367.94 Total Unit lost per hour due to 100 mm2 ACSR (U100=u/1000) 8102.85 93.10 2477.02 316.66 2085.42 3218.57 Total Reduction in Unit lost/Hour due to I*I*R loss (U=U50-U100) 7928.63 91.10 2423.76 309.86 2040.58 3149.37 Average running hour/Feeder (H) 23.825 Total Savings of Units/Year (US=U*H*365) 68948320 792195 21077300 2694541 17745171 27387317 Savings of Units/Year (In MU) 138.64 Average cost of Power Purchase 3.77 Savings due to augmentation of conductor(In Rs Cr.) 52.27

Note-

r of ACSR 50 mm2 at 45 degcel(Res. At 20 deg 0.5524) 0.60805 ohm/KM r of ACSR 100 mm2 at 45 degcel(Res. At 20 deg 0.2792) 0.30732 ohm/KM Average span length 30 Meters Weighted average DT loading 0.635 As illustrated by table above, augmentation of LT ACSR conductor will lead

to a saving of 52.27 Crore/Yr. in sectors from 1 to 57 Gurgaon

146

11.4 Summary of Benefits Expected benefits from above mentioned smart grid initiatives are

summarized in table below:

S.No. Initiative Benefits (in Rs.

Cr. Per year)

1 Advanced Metering Infrastructure (AMI) 87.60

2 Peak Load Management(PLM) 22.94

3 Outage Management System(OMS) 7.95

4 Augmentation of LT conductor 52.27

Total 170.76

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12 FINANCING STRATEGY Plan for development of Smart Grid leading to Smart City Gurgaon involves

Strengthening / modernization of Power Transmission & Distribution

infrastructure to enable 24x7 Power supply as well as making the city DG

sets free. Total estimated cost of above schemes is Rs. 1608crores and it is

to be implemented progressively by 2019.

Funding Mechanism

For funding of the Project, the year wise funding requirement of DHBVN is

as shown in Table below:

Year DHBVN Investment (Rs. Crore)

1st Year 482

2nd Year 1126

Total 1608

Out of estimated cost of 1608 crores, components of 1093.4crores are

eligible under regulation 5.1(d) of Regulation for Disbursement of funds for

renovation and modernisation to remove congestion under PSDF(Power

system development scheme) for sanction of 75% amount of eligible

components. 75% amount of cost of eligible components comes to be

=0.75X1093.4=820crores. Balance amount of 788crores will be arranged

from PFC or will be met through DHBVN ARR.

Requirement of funds year wise will be as tabled

Arrangement of Funds

1st Year (2017-18)

2nd Year (2018-19)

Total (in crores)

Grant from MoP (GoI)

246 574 820

Loan from funding agencies

236 552 788

TOTAL 482 1126 1608

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13 CHALLENGES & STRATEGY FOR IMPLEMENTATION

13.1 Major Challenges

As the project involves dismantlement of existing 11 KV infrastructure,

laying of 11 kV underground electrical network, implementation of SCADA

and AMI , various challenges will be encountered which are required to be

addressed properly. Major challenges and preparedness of DHBVN in

dealing with the issues during execution of project is presented below:

13.1.1 Environmental impacts and mitigation plan

The Project is not expected to have any negative impact on environment

and is rather going to benefit project area at large due to the laying of

underground utilities and removal of congestion besides making the area as

DG set free as running of DG’s is one of the main contributor of

environmental pollution. Moreover the local DG sets are grossly inefficient

in electricity generation as compared to utility Power plants. With the

implementation of smart grid the dependency on diesel generators will

reduce in the city which will definitely reduce the carbon footprints and air

pollution. Per liter of reduction in diesel consumption leads to around 2.68

kg of CO2 emission reduction. So there will be positive impact on the

environment.

Also,with integration of distributed generation like roof-top solar panels, the

dependency on non-renewable energy resources will reduce.

13.1.2 Statutory approvals and clearances

149

Regulatory approvals for Demand Response (ToU Tariff, Dynamic Tariff

etc.) and Demand Side Management (Automatic Load Control) required

from government side.

Clearances for underground cabling, road digging etc, would be sought out

form respective government bodies.

13.1.3 Training and capacity building

Utility operators/employees will be given training sessions on following

modules:

I. Operation and maintenance of Ring main system

II. Cable Fault Identification and remedial measures

III. RMU operation and maintenance

IV. SCADA

V. AMI

VI. PLM

VII. Control room operational issues

VIII. Control room maintenance issues

Training material and schedule shall be provided by the contractor.The

Contractor will also provide support for the maintenance period.

Considering the prevailing power supply scenario in Gurgaon, it is proposed

that Smart Grid technologies will be implemented for garnering benefits not

only from financial gains but also for better consumer relationship, their

engagement in energy management process, green energy benefits and

operational excellence through increased efficiency, better visualization for

fast decision making, optimized work flow, reduced operational cost etc.

The Work will be awarded on “Concept to Commissioning” basis on per unit

150

rate of each activity. Following activities are supposed to be part of project

which would take about 24 months in implementing the project:

Formation of a specialized key team for execution of project.

Creation of office infrastructure.

Deciding a Special committee with financial powers for the smart city

project only.

Explore who are the other power utilities in India or Abroad who have

the expertise for making the distribution system underground and who

can advise us during initial stages of planning, tendering, evaluation

and award of contracts and then during the execution.

Load requirement upto 2031

Engagement of Consultant/Advisor.

Preparation of brief note for getting all the necessary administrative

approvals including the expenditure require to make to complete the

project and the possible means to fund the project of the estimated in

the shape of equity / grant by the government.

Field Survey.

Planning.

Design.

Preparation of detailed BOQ to execute the project.

Preparation of detailed project report (DPR).

Finalization of unit rates for floating of NIT.

Finalization of technical specification of all the items required for

completion of project.

Floating of NIT.

Tendering/Evaluation.

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Work award/allotment. The Work will be awarded on “Concept to

Commissioning” basis on per unit rate of each activity

Execution

Periodical review of Project

After award, it is proposed to complete Smart Grid implementation in 24

months. For implementation of proposed initiatives following steps need

to be taken-

• Timely implementation of the RAPDRP / other schemes already in

progress.

• Development of Smart Grid with all the proposed attributes.

• Establishment of Control Centre for smart grid application integrated

with other IT system.

• Regulatory and policy advocacy for time of use tariff, demand side

management, as part of smart grid development.

• Support/ coordination of district administration as well as other

departments like HUDA, MCG, DMRC, IGL, BSNL, NHAI and Forest

etc. for resolving the ROW issues and for proving the land required in

execution of project.

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14 CONCLUSION In the times to come, everything and every action of us have to be

consumers’ oriented and driven by their expectations and aspirations.

Electricity being the most sought after commodity and having become part

of our lives, it puts a lot of pressure on the electricity transmission and

distribution companies to plan the up-gradation and augmentation of the

existing system. Also, we need to think out of box to find solutions to the

electricity problems and to design the network architecture in a manner that

consumers not only get adequate voltage but also an uninterrupted supply.

Apart from the usual problems which the consumers face, another problem

which the consumers and utility people are facing together is the

congestion and problems of right-of-ways. Smart Grid is the solution to all

such problems. Choosing Gurgaon for developing Smart Grid is the most

appropriate approach which would not only prove to be a role model for

others to follow but also will prove to be preferred destination for

international companies and the people from all across the country.

We hope we shall be able to plan better, execute better and in conformity

with the latest international standards taking in to consideration the latest

available technology as on date.

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ANNEXURES

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