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
5.7.3 Transformation Capacity FY 2017-18( Action Plan 2021-22) ..................... 67
5.7.4 Transformation Capacity FY 2018-19( Action Plan 2021-22) ..................... 68
5.7.5 Transformation Capacity FY 2019-20( Action Plan 2021-22) ..................... 68
5.7.6 Transformation Capacity FY 2020-21( Action Plan 2021-22) ..................... 69
5.7.7 Transformation Capacity FY 2021-22( Action Plan 2021-22) ..................... 69
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
23
• 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
8 Civil work for foundation of DT/RMU/FP etc
No.s 8394 1189.96 1189.96
9 Civil work for underground laying of cable/optical fiber
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
2 IT System and Integration for AMI & PLM
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
9 Civil work for underground laying of cable/optical fiber
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
2 IT System and Integration for AMI & PLM
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
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)
16 Field Equipment for AMI & PLM Lot 14426
17 IT System and Integration for AMI & PLM
Lot 1326
18 Field equipment for PQM & DTMU Lot 3840
59
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
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:
Sr.No. Description /Major head of items
Unit Unit Rate (In lacs)
DLF S/D (As per revised alternate
strategy) Qty. Amt.(In
Lacs) DISTRIBUTION SYSTEM
1 HT U/G Cables (Various Sizes) KM 19.75 282 5570.68
2 LT UG Cables (Various sizes) KM 3.39 50 169.5
3 LT Feeder Pillar No.s 1.77 380 673.62
4 RMU(Ring Main Units) No.s 7.80 563 4392.16
5 Distribution T/F(11/.433kV) No.s 8.89 85 755.65
6 Optical Fiber and PLB-HDPE Pipe KM 1.30 282 366.46
7 Street Light No.s 0.40 0 0
8 ACSR conductor/LT AB cable KM 0.65 1320 858
9 Civil work for foundation of DT/RMU/FP etc
No.s 0.14 1028 145.74
10 Civil work for underground laying of cable/optical fiber
Mtr. 3.42 282 963.48
11 Fencing R/ Mtr 0.04 9711 403.49
12 RCC slabs and route markers No.s 0.002 329000 800.53
13 Cost of road cutting/restoration Sq.mt. 684.85 18259 124.89
60
14 Cost of other minor items/works L/S 135.6
Sub-Total(in Rs Lacs) 15350
SCADA& OMS
15 SCADA & OMS along with civil work required for the project
Lot( Taken as one time cost) 7029
AMI(including DTMU)
16 Field Equipment for AMI & PLM Lot 2219
17 IT System and Integration for AMI & PLM
Lot 1326
18 Field equipment for PQM & DTMU Lot 521
19 Consumer Education and Awareness Lot 10
Sub - total 4076
Total DHBVN A 26455
TRANSMISSION-HVPN
20 Substations & Lines 0
TOTAL (HVPN) - B 0
Total Consultancies Charges – C (2% of (A+B)) 529
GRAND TOTAL (A+B+C)(In Lacs) 26984
GRAND TOTAL (In Crores) 270
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:
Sr.No. Description /Major head of items
Unit Unit Rate (In lacs)
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
3 LT Feeder Pillar No.s 1.77 1120 1985.41
4 RMU(Ring Main Units) No.s 7.80 2437 19011.89
5 Distribution T/F(11/.433kV) No.s 8.89 1591 14143.99
6 Optical Fiber and PLB-HDPE Pipe KM 1.30 2538 3298.12
7 Street Light No.s 0.40 0 0
8 ACSR conductor/LT AB cable KM 0.65 8800 5720
9 Civil work for foundation of DT/RMU/FP etc
No.s 0.14 5148 729.82
10 Civil work for underground laying of cable/optical fiber
Mtr. 3.42 2538 8671.29
11 Fencing R/ Mtr 0.04 37049 1539.38
12 RCC slabs and route markers No.s 0.002 2961000 7204.76
13 Cost of road cutting/restoration Sq.mt. 684.85 164333 1124.01
14 Cost of other minor items/works L/S 1148.5
Sub-Total(in Rs Lacs) 115600
SCADA& OMS
62
15 SCADA & OMS along with civil work required for the project
Lot( Already taken as one time cost in DLF City S/Div.) 0
AMI(including DTMU)
16 Field Equipment for AMI & PLM Lot 12207
17 IT System and Integration for AMI & PLM
Lot( Already taken in DLF City S/D Part) 0
18 Field equipment for PQM & DTMU Lot 3319
19 Consumer Education and Awareness Lot 90
Sub - total 15616
Total DHBVN A 1312.16
TRANSMISSION-HVPN
20 Substations & Lines 0
TOTAL (HVPN) - B 0
Total Consultancies Charges – C (2% of (A+B)) 2624
GRAND TOTAL (A+B+C)(In Lacs) 133840
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
5.7.3 Transformation Capacity FY 2017-18( Action Plan 2021-22)
2017-18
No. of Sub-stations with
Installed Capacity starting
2017-18
Proposed Augmentations in No. with capacity ending 2017-18
Proposed new Sub-Stations in
No. with Capacity ending
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
5.7.4 Transformation Capacity FY 2018-19( Action Plan 2021-22)
2018-19
No. of Sub-stations with
Installed Capacity starting
2018-19
Proposed Augmentations in No. with capacity ending 2018-19
Proposed new Sub-Stations in
No. with Capacity ending
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
5.7.5 Transformation Capacity FY 2019-20( Action Plan 2021-22)
2019-20
No. of Sub-stations with
Installed Capacity starting
2019-20
Proposed Augmentations in No. with capacity ending 2019-20
Proposed new Sub-Stations in
No. with Capacity ending
2019-20
Final sub-stations with Capacity
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
5.7.6 Transformation Capacity FY 2020-21( Action Plan 2021-22)
2020-21
No. of Sub-stations with
Installed Capacity starting
2020-21
Proposed Augmentations in No. with capacity ending 2020-21
Proposed new Sub-Stations in
No. with Capacity ending
2020-21
Final sub-stations with Capacity
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
5.7.7 Transformation Capacity FY 2021-22( Action Plan 2021-22)
2020-21
No. of Sub-stations with
Installed Capacity starting
2020-21
Proposed Augmentations in No. with capacity ending 2020-21
Proposed new Sub-Stations in
No. with Capacity ending
2020-21
Final sub-stations with Capacity
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
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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
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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.
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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.
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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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107
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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
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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
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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
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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
Cycle management of Equipments
UPS of Control Centre (20 kVA Redundant UPS) Lot 1 1 2 Uninterrupted power
supply
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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
Cycle management of Equipments
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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)
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• 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:
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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
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• 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.
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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).
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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
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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
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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
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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
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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
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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