a joint initiative of government of india and government...

24 X 7 POWER FOR ALL

A JOINT INITIATIVE OF GOVERNMENT OF INDIA AND GOVERNMENT OF NAGALAND

MARCH 2016

Government of India

Piyush Goyal Minister of State (Independent Charge) for Power, Coal and New & Renewable Energy

Foreword Electricity consumption is one of the most important indicators and tool to achieve rapid economic growth and socio-economic development that decides the development level of a nation. The Government of India is committed to improve the quality of life of its citizens through higher electricity consumption. Our aim is to provide each household access to electricity, round the clock. The “Power for All” programme is a major step in this direction. Nagaland is one of the important states of North-Eastern part of the country with high potential of rapid growth. However, the issues like low per capita consumption than national average and more than one third of the total house-holds yet to be electrified would need to be brought into focus. The growth of industrial sector which is essential to clock high pace of growth would also come as a sequel to improved electricity scenario. This joint initiative of Government of India and Government of Nagaland aims to enhance the satisfaction levels of the consumers and improve the quality of life of people through 24x7 power supply at affordable cost. This would lead to rapid economic development of the state in primary, secondary & tertiary sectors resulting in inclusive development. I compliment the Government of Nagaland and wish them all the best for implementation of this programme. The Government of India will complement the efforts of Government of Nagaland state in bringing uninterrupted quality power to all households, industries, commercial businesses, public needs & any other electricity consuming entities and adequate power to agriculture as per the state policy.

Government of Nagaland

T. R. Zeliang Chief Minister of Nagaland

Foreword

Power sector is most critical component of state’s growth driving mechanism and thus has a direct influence on state’s economic well being. An efficient, resilient and financially sustainable power sector is essential to stimulate growth and prosperity in the state. The availability of reliable, quality and affordable power can ensure growth of all sectors of economy.

Nagaland is one of the North-Eastern Indian states offering opportunities for high growth and rapid development. Ensuring the reliable and affordable power lies at the core of this growth ambition of the State. The state Government is committed to do everything in order to realize this dream for its citizens and propel the State to be in league of developed States of the Indian Union. The immediate priorities should be to have a smart power purchase mechanism and revamping of transmission and distribution network.

In this scheme of things “24x7 Power for all” programme plays a pivotal role. Conceived with the objective of providing 24x7 quality, reliable and affordable power for all, this programme takes a holistic approach for addressing the concerns across the value chain in power sector.

On behalf of Government of Nagaland, I would like to thank Government of India, Hon’ble Prime Minister and Hon’ble Minister of Power for implementation of this programme.

https://en.wikipedia.org/wiki/Chief_Minister_of_Haryana

Government of India

Government of Nagaland

Joint Statement

The State of Nagaland is committed to provide quality life to people of state. Electricity supply serves as an important means to achieves this. The programme of “24x7 Power for All” is an important step in this direction and this programme will be implemented by Government of Nagaland (GoN) with the objective to connect the unconnected in phased manner by FY 2018-19 to ensure supply of quality, reliable and affordable power to all category of consumers on 24x7x365 basis. Government of Nagaland would ensure that all the necessary steps outlined in the PFA document are taken up in terms of capacity addition, power procurement, strengthening the required transmission and distribution network, encouraging renewable, demand side management & energy efficiency measures, undertaking customer centric initiatives, reduction of AT & C losses, bridging the gap between ACS & ARR, and following good governance practices in implementation of all central and state government schemes.

Government of India (GoI) would supplement the efforts of Government of Nagaland by fast tracking resolution of key issues pertaining to generation, expediting the additional interstate connectivity and ensuring optimum allocations in various distribution schemes, as per the provisions of applicable policies. Government of Nagaland would endeavor to implement the programme within the targeted time frame of FY 2018-19 or even earlier than the targeted date. The central and state governments would meet regularly to review the progress of the programme over the next three (3) years and would strive to achieve the objectives of the programme by taking the necessary steps as envisaged in the PFA document.

24X7 POWER FOR ALL (NAGALAND) 1

CONTENTS

EXECUTIVE SUMMARY 1

CHAPTER 1: INTRODUCTION 3

CHAPTER 2: FACTS ABOUT NAGALAND 5

CHAPTER 3: CONSUMPTION PATTERN AND ELECTRIFICATION STATUS 6

CHAPTER 4: DEMAND AND SUPPLY SCENARIO 8

CHAPTER 5: GENERATION PLAN 12

CHAPTER 6: TRANSMISSION PLAN 17

CHAPTER 7: DISTRIBUTION PLAN 23

CHAPTER 8: RENEWABLE ENERGY STATUS AND PLAN 38

CHAPTER 9: ENERGY EFFICIENCY 42

CHAPTER 10: FINANCIAL VIABILITY 47

CHAPTER 11: OTHER INITIATIVES 54

CHAPTER 12: YEAR WISE ROLL OUT PLAN 58

CHAPTER 13: SECTOR WISE INVESTMENT PLAN & FUND REQUIREMENT 60

ANNEXURES

ANNEXURE-I : CATEGORY-WISE GROWTH IN CONSUMERS 61

ANNEXURE-II : CENSUS 2011 DATA OF HOUSEHOLDS IN NAGALAND 62

ANNEXURE-III : DETAILED CALCULATION OF ENERGY DEMAND IN THE STATE OF NAGALAND UP TO FY 2018-19

63

ANNEXURE-IV : BREAK UP & DETAILS OF CAPACITIES EXISTING AND LIKELY

TO BE ADDED YEAR WISE

65

ANNEXURE-V : EXISTING INTRA & INTER STATE TRANSMISSION SYSTEM

68

ANNEXURE-VI : YEAR WISE PROPOSED INVESTMENT PLAN FOR INTRA STATE TRANSMISSION SYSTEM

70


ANNEXURE-VII-A : DETAILS OF POWERGRID IN NAGALAND 73

ANNEXURE-VII-B : POWERGRID IN NAGALAND (EXISTING TRANSMISSION LINE DETAILS AND PROPOSED SUBSTATIONS & LINES)

74

ANNEXURE-VIII-A : DISTRICT WISE OVERALL PLAN AND FUND REQUIREMENT AGAINST ONGOING PROJECTS UNDER 12TH PLAN RGGVY

75

ANNEXURE-VIII-B : DISTRICT WISE OVERALL PLAN AND FUND REQUIREMENT AGAINST ONGOING PROJECTS UNDER NERPSIP DMS SCHEME UNDER WORLD BANK FUNDING

77

ANNEXURE-VIII-C : DISTRICT WISE OVERALL PLAN AND FUND REQUIREMENT AGAINST ONGOING PROJECTS UNDER DDUGJY

79

ANNEXURE-IX-A : DISTRICT WISE OVERALL PLAN AND FUND REQUIREMENT AGAINST FUTURE PROJECTS IPDS SCHEME IN 12 TOWNS OF 11 DISTRICTS OF NAGALAND

81

ANNEXURE-IX-B : DISTRICT WISE OVERALL PLAN AND FUND REQUIREMENT AGAINST FUTURE PROJECTS UNDER DDUGJY IN 11 DISTRICTS OF NAGALAND

85

ANNEXURE-IX-C : THE SUMMARY OF OVERALL PLAN AGAINST FUTURE PROJECTS

89

ANNEXURE-X : YEARWISE PROPOSED INFRASTRUCTURE PLAN FOR ALREADY SANCTIONED & FUTURE SCHEMES

91

ANNEXURE-XI : DETAILS OF SYSTEM STRENGTHENING PLAN OF NAGALAND FY 2015-16 TO 2018-19

119

ANNEXURE-XII : POWER PURCHASE COST PROJECTED BY DOPN FOR FY 2015-16

122

ANNEXURE-XIII : AVERAGE BILLING RATE 123

MAPS


24x7 Power for All (24x7 PFA) is a Joint Initiative of Government of India (GoI) and State Governments with the objective to make 24x7 power available to all households, industry, commercial businesses, public needs, agriculture & any other electricity consuming entity by FY 2018-19 as per the State policy.

This roadmap document aims to meet the above objectives for the state of Nagaland. Nagaland stands at 31st position with approximately 0.05% of total installed capacity in the country. Nagaland is yet to achieve 100% electrification and 141049 households are un-electrified in the state (Both rural & urban) as of year 2015. The per capita consumption of power in Nagaland has been 311Units which is much lower than the National Average of 1010 during FY 2014-15.

GROWTH IN DEMAND

Nagaland has observed peak power shortages between 15-22% and energy shortage in the range of 5-19% respectively during last 3-4 years. In order to achieve the objective of 24 x 7 power supply to all, it has been estimated to see an increase in peak demand from 145 MW (FY 2014-15) to 265 MW in FY 2018-19 with corresponding increase in energy requirement from 721.14 MU in FY 2014-15 to 1169.72 MU in FY 2018-19.

The future demand has been derived by estimating the urban and rural household consumption taking into account the growth in number of electrified households on the one hand and the growth in average consumption per household on the other. Considering combined growth rate based on five (5) years CAGR (from FY 2008-09 to FY 2013-14) and the future growth potential of industrial & commercial activity, average CAGR of 26% per annum has been adopted to project the consumption of other than domestic category consumers.

SUPPLY ADEQUACY

The available capacity (installed as well as allocated share) for the State as on 31st March 2015 was 144.02 MW. In order to meet the estimated increased demand for providing 24x7

power supply, the state has already planned additional capacity availability of 157.25 MW by FY 2018-19 through own generating stations, renewable energy sources, central generating stations and long term/medium term PPAs in a phased manner. Out of this, 72.25 MW shall be added through non-conventional energy sources (Solar & SHP) and balance 85.00 MW through conventional sources. It is to be noted that after consideration of 24x7-PFA requirement, the state will have a deficit of about 6.13% to 34.60% in terms of peak demand during the period FY 2015-16 to FY 2018-19. During the same period, the state will also have deficit of energy availability in the range of 5.68% to 19.64% except during FY 2016-17 when the state will have surplus energy availability to the tune of 1.20%. Therefore, Nagaland State will remain as power deficit state during the period of study (i.e. from FY 2015-16 to FY 2018-19) having deficit in both peak power and energy availability with the exception of FY 2016 – 17in which the State will have energy surplus.

As the state generation is heavily dependent on hydro (about 30% to 40% during the study period), the above deficit energy scenario may change on year to year basis depending upon monsoon scenario in the state. However, it is expected that the State of Nagaland still will be an energy deficit state for the period FY 2015-16 to FY 2018-19. In poor monsoon years, the deficit of energy is expected to be more due to less generation from hydro power projects. On the other hand, in the years of above-average / good monsoon scenario, the contribution of hydro power projects is expected to be higher resulting in improvement in the scenario. As deliberated above, the State of Nagaland is expected to be an energy deficit state during the entire period of study. In order to mitigate the above situation, Government of Nagaland would have to effectively plan through comprehensive power procurement initiatives on short term, medium term & long term basis and look for

EXECUTIVE SUMMARY


procurement of power either through competitive bidding or through other sources such as enhanced allocation from CGS. Further, the peak demand and energy requirement of the State can also be effectively reduced through proper implementation of DSM & Energy efficiency measures in the state of Nagaland. Government of Nagaland (GoN) has also proposed implementation of Zungki HEP (24 MW), Lower Tizu HEP (36 MW) and Tizu Valley HEP (15 MW). These projects are likely to be commissioned after FY 2018-19 and will be helpful in meeting the future power requirement of the State of Nagaland ADEQUACY OF TRANSMISSION NETWORK

The state is served by a network of Inter- state transmission lines at 220 kV level. The existing ISTS transmission system capacity is adequate for meeting the present power requirement. In ISTS system, Power-grid/State has undertaken/ planned a number of transmission works for further strengthening the connectivity of Nagaland state grid with national grid and it shall be just adequate to meet the projected power demand of Nagaland by FY 2018-19 for 24x7 PFA in the state. The existing Intra-state transmission capacity at 132 kV & 66 kV level are 226.5 MVA & 170 MVA respectively to cater the current maximum demand 145 MW of the state. As per the state’s transmission plan, the Intra-state transmission capacity will be increased to 820.5 MVA at 132 kV level FY 2018-19 which will be adequate to meet the projected Power demand of 265.00 MW of the state by FY 2018-19. The Intra-state transmission system has been planned with an investment of Rs388.94Crores from FY 2014-15 to FY 2018-19 towards capacity addition in the state to meet the requirement as envisaged for 24x7 PFA.

ADEQUACY OF DISTRIBUTION NETWORK As per the information, Dept. of Power, Nagaland (DOPN) is serving about 2.55 Lakhs consumers including 2.38 lakhs domestic consumers in the state. As per the survey undertaken by the state, still there are about 1.16 lakhs rural & 0.25 lakhs urban un-electrified households in the state which are proposed to be electrified during next four (4) financial years. The state has undertaken &proposed a requirement of capital expenditure of Rs 382.48 Crores in DDUGJY, Rs. 230.33 Crores in IPDS and Rs. 106.75 Crores in NERPSIP DMS for feeder segregation, providing electricity access to all rural households, system strengthening& network up -gradation in rural & urban areas through a planned capacity addition of 326.90 MVA at 66/11kV & 33/11 kV, 95.23 MVA at DT level and creation of 33 kV, 11kV ABC & Bare conductor lines, U/G cables, LT lines, Electronic consumer meters, Capacitor bank etc.

The proposed distribution network with projected addition through GOI/State schemes (DDUGJY, IPDS, RGGVY and NERPSIP) would be adequate under projected peak load addition.

The AT & C losses of the state are projected to be reduced from 61.71 % in FY 2014-15 to 31.71% by FY 2018-19 as per state data.

FINANCIAL POSITION

As the total power supply responsibility in the state is solely looked after by the Government department, no separate accounts are maintained. However based on tariff orders of FY 2015-16, the financial viability scenario has been worked out. It seems that across all the scenarios, losses are there and on average 14%-18% tariff hikes would be required for achieving turn around by FY 2018-19.


Access to electricity on 24X7 basis for all its citizens has become synonymous to cause of social equality. It means much more than merely an act of infrastructure development to any nation and thus this issue has acquired significant dominance on the national as well as state agenda. Endeavour to perk-up the growth in electricity consumption to stay in pace with national/global benchmark therefore are to be taken up with top most priority. Under the Indian Constitution, electricity is a concurrent subject and distribution of electricity falls under the purview of the respective State Government/State Power Utility. As per Electricity Act 2003, it is the duty of a distribution licensee to develop and maintain an efficient, co-ordinated and economical distribution system in his area of supply and to supply electricity in accordance with the provisions contained in the Act. The State Electricity Regulatory Commission (SERC) shall specify or enforce standards with respect to quality, continuity and reliability of service by licensees. Accordingly, State Electricity Regulatory Commissions (SERCs) have notified the Standards of Performance specifying maximum allowable time for restoration of supply due to forced breakdowns and Supply Code specifying the supply voltages & frequency etc, to be followed by DISCOMS. SERCs also monitor the performance of distribution companies on the basis of notified Performance of Standards. OBJECTIVES OF THE 24X7 POWER FOR ALL – JOINT INITIATIVE

To supplement the efforts towards achieving this objective, Government of India and Government of Nagaland have taken a joint initiative to provide 24 X 7 power in the state to all consumers. This initiative aims at ensuring uninterrupted supply of quality power to existing consumers and providing access to electricity to all unconnected/upcoming consumers by FY 2018-19.

The initiative of 24x7 Power supply to all encompasses mainly the following:

i. Reliable & quality 24X7 power supply to the existing consumers in a phased manner within a period of three years from the date of commencement of the programme.

ii. All unconnected/upcoming households to be provided access to electricity in a time bound manner ultimately by FY 2018-19. States have the liberty to hasten the process by taking accelerated steps, if required.

iii. To ensure adequate capacity addition planning & tie ups for power from various sources at affordable price to meet the projected increase in power demand for future.

iv. Strengthen the Transmission and Distribution network to cater to the expected growth in demand of existing as well as forthcoming consumers.

v. Monitoring the timely commissioning of

various generating plants, transmission and distribution infrastructure to meet the expected growth in demand.

vi. Put in place a strategy to ensure reduction of

AT&C losses as per the agreed loss reduction trajectory and methodology & steps required to be taken at every level of distribution in this regard.

vii. Overall Power Supply Improvement to be achieved by undertaking measures such as energy mix optimization, reduction in power operational in-efficiency of state generation plant(s) and optimal fuel procurement policy.

viii. Financial measures including investment

rollout plans and analysis to assess the financial impact from implementation of 24x7-PFA.

ix. Introduce modern technologies to monitor reliable supply like sub-station automation, providing adequate communication infrastructure, GIS, Reliability, Centralized Network Analysis and Planning tools, SAP driven ERP systems, DMS (Distribution Management Systems), OMS (Outage Management System), etc.

CHAPTER – 1: INTRODUCTION


x. To take essential measures for meeting the performance standards as laid down by SERC.

An Action plan would be drawn to achieve the above aims and objectives. The plan will be executed by the State Government with the support of Government of India, wherever necessary, as per their approved plans, schemes and policies. This joint initiative of Government of India and Government of Nagaland aims to enhance the satisfaction levels of consumers, improve the quality of life of people, and increase the economic activities resulting into inclusive development of the state. METHODOLOGY FOR PREPARATION OF THE ACTION PLAN FOR THE 24X7 POWER FOR ALL Accordingly the methodology adopted to prepare the ‘Action Plan’ for 24x7 PFA includes inter-alia: 1) Projection of average per day consumption

of rural and urban households based on respective historical compounded annual growth rates (CAGR) during the past years and also considering the aspirational growth perspectives in consultation with state.

2) Projection of demand of consumers encompassing commercial, industrial, agricultural and all remaining consumers have been carried out under others category based on past data and historical CAGR recorded for the state during the past

years after discussing with state and factoring in the aspirational growth perspectives.

3) Assess the power requirement of un-

electrified households and draw up a time bound plan for electrification of all households.

4) Project the annual energy requirement and maximum demand by aggregating the requirement of all consumer categories and applying an appropriate load factor.

5) Prepare a broad plan to meet power demand in future through additional generation capacity proposed in the state and quantum for additional procurement required.

6) Assess the financial implications on utilities and per unit implication on tariff for procuring additional energy to meet the energy requirement of all segments of consumers. Assess the adequacy of the network - both inter-state and intra-state transmission as well as distribution so as to meet the increased / expected / projected power requirement of all consumer categories of the state.

7) Conduct sensitivity analysis on various parameters namely tariff, AT&C loss reduction, etc.

8) Set monitorable targets to achieve the goal of 24x7 PFA in a cost effective manner to the consumers of the state.


Nagaland is the 25th largest state with an area of 16,579 km2 and the 24th largest by population (as per census 2011) with total population of 1,978,502 (1,024,649 male and 953,853 female). The per capita income of the state in FY 2014-15 was Rs. 85544 only. It is bordered by Myanmar (Burma) to its East, Arunachal Pradesh and Parts of Assam to its north, Assam to the west and Manipur to its south. Nagaland has forest area of 8,629 km2, which is about 52.04% of its geographical area.

The brief profile of Nagaland State of India is as follows:

Table-2.1

Brief Profile of Nagaland

Sl. No.

Description Unit

1. Area Sq. Km. 16579 2. Population (Persons

as per 2011 census)

- Rural Nos. 1407536 - Urban Nos. 570966

3. Per Capita income (FY 2014-15)

Rs. 85544*

4. No. of Districts Nos. 11 5. State GDP growth

rate (FY 2013-14) % 13.24**

6 Total Urban Households ( FY 2014-15)

Nos. 143077

7 Total Rural Households (FY 2014-15)

Nos. 293140

8 Total Electrified Nos. 118511

Sl. No.

Description Unit

Urban Households ( FY 2014-15)

9 Total Electrified Rural Households ( FY 2014-15)

Nos. 176657

10 No. of un-electrified Households (FY2014-15)

Nos. 141049

*Press Information Bureau, Ministry of Statistics & Programme Implementation. **Wikipedia The Department of Power, Nagaland is the sole Agency responsible for Generation, Transmission & Distribution of Power throughout the State. It is a power starved state despite having substantial Hydro Potential. It still depends on the power allocation from the Central public sector units (CPSUs) which barely meets certain percentage of demand during the lean season. At present the Deptt. is headed by Two (02) Chief Engineers - CE (D&R) & CE (T&G). The Head office includes functions such as commercial, Account, Establishment, Transmission Planning, Generation Planning, RAPDRP, Rural Electrification and centralized civil section. The individual Circles are looked after by Superintending Engineers whereas the Division & Sub-Division offices are managed by Divisional Engineers & Asstt. Engineers respectively. Nagaland has shown peak power shortages of 18.2% & 17.24% respectively and energy shortage of 13.7% & 5.04% respectively during FY 2013-14 & FY 2014-15. It is yet to achieve 100% electrification and 141049 Households are un-electrified in the state (Both rural & urban) as of FY 2014-15, which are proposed to be electrified by FY 2018-19 in phased manner.

CHAPTER – 2: FACTS ABOUT NAGALAND


As per Census 2011 data, there were about 4.00 lakhs households in the state, out of which 2.85 lakhs were in rural areas and balance 1.15lakhs were in urban areas. Out of 2.85 lakhs rural households, 2.14lakhs (75.09%) were electrified and balance 0.71 lakhs (24.91 %) were un-electrified. In urban areas, out of total of 1.15 lakhs households, 1.12 lakhs (97.40 %) were electrified and balance 0.03 lakhs (2.60 %) were un-electrified. Nagalandis still striving to achieve 100% electrification status. The details are at Annexure-II.

The projection of total number of households in FY 2014-15 has been carried out based on census figures of 2011 and considering CAGR of the past 10 years. However, the data for total number of electrified households in urban and rural areas in FY 2014-15 is also compared with state data and the latest available data from state has been considered for projecting the future household consumption.

The details of households in the State of Nagaland based on Census figures and as per GoN are as under:

Table-3.1 Nos. of Households in Nagaland in FY 2014-15

Particulars Census

2001 Census 2011

CAGR As projected from Census

figures

As per GoN

Finally Adopted

Total Households 332050 399965 1.88% 436217 As per Census

436217 Rural Households 265334 284911 0.71% 293140 293140 Urban Households 66716 115054 5.60% 143077 143077 Total Electrified Households 211194 326405 4.45% 388496 295168 295168

Rural Electrified H/H 150929 214319 3.57% 246590 176657 176657 Urban Electrified H/H 60265 112086 6.40% 143663 118511 118511 Total Un-electrified H/H 120856 73560 - 47721 141049 141049 Rural Un-electrified H/H 114405 70592 - 46550 116483 116483 Urban Un-electrified H/H 6451 2968 - - 24566 24566 Presently, there are about 2.95 lakhs electrified households in the state (Rural 1.76 lakhs and Urban 1.18 lakhs). Thus there are total of around 1.16 lakhs un-electrified households in rural area and around 0.25 lakhs un-electrified households in urban area. At present, out of the total consumption in the state, domestic category of consumers consume about 84.30%, commercial around 11.84% and industrial around 2.25 %.

The category wise Growth in consumers from FY 2009-10 to FY 2014-15 is furnished in Annexure-I.

Load Projection

Based on the urban & rural consumption data provided by GoN, present per household consumption has been assessed as 1.75 units/day in rural area and 5.20 units/day in urban area as shown in Table 3.2.

CHAPTER – 3: CONSUMPTION PATTERN AND ELECTRIFICATION STATUS


Table-3.2

ESTIMATION OF EXISTING PER HOUSEHOLD CONSUMPTION FOR FY 2014-15

Sl. No. Particulars

Unit As per State data (FY 2014-2015)

1 Total Households in State Nos. 436217

2 Total Urban Households Nos. 143077

3 Total Rural Households Nos. 293140

4 Total Electrified Households Nos. 295168

5 Total Electrified Households - Urban Nos 118511

6 Total Electrified Households - Rural Nos 176657

7 Balance Un-electrified Households Nos. 141049

8 Balance Un-electrified Households - Urban Nos. 24566

9 Balance Un-electrified Households - Rural Nos. 116483

10 Electrification of houses under 12th Plan RGGVY Nos. 0

11 Annual energy sold in the State during FY 2014-15 MU 400.77

12 Annual Domestic energy sold in the state during FY 2014-15 % 84.30

13 Annual Domestic energy sold in the State during FY 2014-15 MU 337.85

14 Average Annual Energy Consumption per household during FY 2014-15 kWh 1144.60

15 Average Daily Energy Consumption per household during FY2014-15 kWh 3.14

16 Annual Total Rural Consumption MU 112.75

17 Annual per household rural consumption kWh 638.24

18 Annual Total Urban Consumption MU 225.10

19 Annual per Household Urban Consumption kWh 1899.40

20 Daily per household rural consumption kWh 1.75

21 Daily per household Urban consumption kWh 5.20

The daily per household Rural and Urban consumption as worked out above has been considered for projection of Annual energy requirement in the state from FY 2015-16 to FY 2018-19


There has been energy shortage throughout the previous years in Nagaland, although, it has decreased from 13.7% in FY 2013-14 to 5.04 % in FY 2014-15. The Power Supply Scenario in

Nagaland (as per state data) from the FY 2009-10 to FY 2014-15 is as under-

Table-4.1 Power Supply Scenario

Period/Items Unit FY

2009-10 FY

2010-11 FY

2011-12 FY

2012-13 FY

2013-14 FY

2014-15 FY

2015-16 (*)

Peak Demand at state periphery

MW 100 106 112 120 132 145 -

Peak Met at state periphery MW 90 96 87 102 108 120 123.5 Peak Deficit (-)/ Surplus (+) MW (-)10 (-)10 (-)25 (-)18 (-)24 (-)25 - Peak Deficit (-)/ Surplus (+) % (-) 10 (-) 9.4 (-) 22.3 (-)15 (-)18.2 (-)17.24 -

Energy Requirement at state periphery

MU 560.0 578.4 655.1 662.3 710.0 721.14 -

Energy Availability at state periphery

MU 476.6 521.2 528.0 546.2 612.6 684.82 566.42

Energy Deficit (-)/ Surplus (+) MU (-)83.4 (-)57.2 (-)127.1 (-)116.1 (-)97.4 (-)36.32 - Energy Deficit (-)/ Surplus (+) % (-)14.9 (-)9.9 (-)19.4 (-)17.5 (-)13.7 (-)5.04 -

Source: State Power Utilities (*) Data upto 3rdQtr (April 2015-Dec 2015) The reasons for deficit have been less internal/ own generation and Transmission/Distribution constraints.

The energy requirement including all categories of consumers has posted a Compound Annual Growth Rate (CAGR) of 5.19% as against the

supply growing at a CAGR of 7.52% based on data from year FY 2009-10 to FY 2014-15. The scenario is exhibited below:

2009 - 10 2010 - 11 2011 - 12 2012 - 13 2013 - 14 2014 - 15

Energy Requirement at state periphery (MU) 560.00 578.40 655.10 662.30 710.00 721.14

Energy Availability at state periphery (MU) 476.60 521.20 528.00 546.20 612.60 684.82

0.00

100.00

200.00

300.00

400.00

500.00

600.00

700.00

800.00

Mill

ion

Uni

ts

Energy Requirement and Availability

CAGR-7.52%

CAGR-5.19%

CHAPTER –4: DEMAND AND SUPPLY SCENARIO


The base year for the purpose of beginning the future assessment has been considered as FY 2014-15 which has an aggregated demand of 721.14Million Unit (MU).

Demand Estimation Methodology

For the purpose of estimation, power consumers have been broadly classified into the domestic consumers and others (commercial, industrial, agriculture etc.). The demand projection has been done taking into account the demand for 24X7 power supply under following heads:

a) Demand growth to a targeted value of already electrified households (both Urban and Rural).

b) Demand growth from electrification of un-electrified households (both Urban and rural).

c) Demand from electrification of newly constructed households (both Urban and Rural).

d) Demand on account of consumers other than domestic consumers including agricultural consumers, if any.

Considering the expected growth of electrification in the state in the coming years, all the Rural un-electrified households have been considered to be brought under electrification at the rate of 44% for FY 2016-17, 42% for FY 2017-18 and 14% for FY 2018-19 and all the Urban un-electrified households have been considered to be brought under electrification at the rate of 41% each for FY 2016-17 & FY 2017-18 and 18% for FY 2018-19.

The assumptions for projection of demand under different categories are described below:

• Based on the urban & rural consumption data provided by GoN, present (FY 2014-15) per household consumption has been assessed as 1.75 units/day in rural area and 5.20 units/day in urban area.

• Energy requirement for rural & urban households have been computed based on the latent demand growth observed in past. The daily per household rural consumption is estimated to increase from the current levels of 1.75 units/day to 2.76 units/ day by FY 2018-19 (following CAGR of 12%) and daily per household urban consumption is estimated to increase from the current

levels of 5.20 units/day to 8.48units /day by FY 2018-19 (following CAGR of 13%).

• Demand projections for consumers other than domestic have been done based on computation of CAGR from FY 2008-09 to FY 2013-14 as per data obtained from NERC Tariff order 2015-16. 25.79% constant growth in energy requirement per annum has been taken keeping in view the growth potential in industrial and commercial activities due to assured power availability.

PROJECTIONS OF ANNUAL ENERGY REQUIREMENT OF THE STATE

The annual energy requirement at state periphery works out to be around 747.53 MU in FY 2015-16 which is scaling up to around 1169.72MU in FY 2018-19 after considering the following.

a) Demand of already electrified households

The annual energy consumption for existing households works out to be 544.78 MU in FY 2018-19.

b) Demand from electrification of un-electrified households

According to the state data there are around 141049 un-electrified households (Rural – 116483 & Urban – 24566) which are assumed to be electrified at the rate of 44%, 42% & 14% per year for FY 2016-17, FY 2017-18 and FY 2018-19 for Rural Consumers and at the rate of 41% per year each for FY 2016-17 & FY 2017-18 & 18% for FY 2018-19 for urban Consumers. The annual energy requirement on account of un-electrified households after electrification is estimated as 193.39MU in FY 2018-19.

c) Demand from electrification of newly constructed households

To account for energy requirement of new houses which are likely to be constructed in the coming years, projection have been done considering CAGR of 5.60% (census of 2001 & 2011) on number of urban households and CAGR of 0.71% in number of rural households based on census data. The projected energy consumption of this category works out to 116.33MU in FY 2018-19.


Demand on account of consumers other than domestic consumers.

The annual energy requirement for consumers other than domestic has been calculated after discussion with state officers assuming that such segment of consumers are expected to

grow at a constant CAGR of 25.79% per annum. Accordingly the energy consumption of other than domestic consumers works out to be 157.54MU in FY 2018-19.The summary of energy calculation during the next four years is given in the table hereunder.

Table-4.2

SUMMARY OF ANNUAL ENERGY REQUIREMENT PROJECTIONS (in MU)

Sl. No.

PARTICULARS→ ↓

YEARS FY

2015-16 FY

2016-17 FY

2017-18 FY

2018-19 1 Annual Energy Requirement including additional

energy requirement for existing electrified households

380.73 429.08 483.04 544.78

2 Annual Energy Requirement for Electrification of un-electrified Household

0.00 65.47 144.77 193.39

3 Annual Energy Requirement for newly constructed Household

18.69 43.27 75.20 116.33

TOTAL DOMESTIC 399.42 537.82 703.01 854.5

4 Total Annual Energy Requirement including additional energy requirement - Other than Domestic Consumers (with 25.79% growth per annum)

79.15 99.56 125.24 157.54

GRAND TOTAL 478.57 637.38 828.25 1012.04

Annual energy requirement at state periphery

The table below shows values of projected energy requirement at the state periphery considering T&D loss trajectory as informed by state for the FY 2015-16 to FY 2018-19.

Table-4.3

ANNUAL ENERGY & PEAK DEMAND REQUIREMENT AT STATE PERIPHERY PARTICULARS Unit FY

2015-16 FY

2016-17 FY

2017-18 FY

2018-19 Energy requirement as per demand projections MU 478.57 637.38 828.25 1012.04 Distribution losses* % 33.66 25.89 18.11 10.34 Intrastate Transmission Losses % 3.5 3.5 3.5 3.5 Energy requirement at state periphery MU 747.53 891.19 1048.15 1169.72 Load Factor as per CEA Report of 18th EPS for Nagaland % 52.00 51.40 50.90 50.40 Peak Demand MW 164.00 198.00 235.00 265.00 *As per T&D loss trajectory Provided by the State

The load factors have been considered based on the data furnished by 18th EPS of CEA for the years shown above in Table 4.3.

The detailed calculation of energy demand under different categories in the state up to FY 2018-19 is given in Annexure-III. Keeping in view the unrestricted demand, the energy requirement at consumers end is estimated as 1012.04 MU which corresponds to 1169.72 MU at state periphery (considering Transmission &distribution loss trajectory as informed by state) for all categories of consumers by FY 2018-19.

Accordingly the maximum demand requirement of the state is projected to increase to around 265.00 MW by FY 2018-19.

As per projections made in 18th EPS of CEA, the projected energy demand and peak load for the state of Nagaland would be 954.17MU and 216.12 MW respectively in FY 2018-19 as against the now calculated energy demand of 1169.72MU (22.59 % higher) and peak load of 265.00 MW(22.60 %higher) in FY 2018- 19.


As against energy demand of 1169.72MU in FY 2018-19 at the state periphery, the energy availability projections from all possible sources as per Generation Plan by FY 2018-19 works out to 977.74 MU (shown in next chapter) indicating a deficit of 191.98 MU. The adoption of various energy efficiency measures like energy efficient lighting (use of LEDs), adopting demand side management

initiatives like DELP -DSM based efficient lighting measures or by adopting accelerated AT &C loss reduction targets would help in reducing the peak demand and energy requirement of the state.

However, an assessment of the adequacy of Generation, Transmission and Distribution infrastructure vis-a-vis the projected demand by FY 2018-19 has been made in the subsequent chapters.

0

500

1000

1500

FY 2015-16 FY 2016-

17 FY 2017-18 FY 2018-

19

Ener

gy in

MU

Projected Annual Energy Requirement at consumer end

All other categories except domestic

Newly constructed houses

Unelectrified households

Already existing electrified households

Million Units


The generation plan will ensure adequate capacity addition planning & tie ups for power from various sources at affordable price to meet the projected increase in power demand for future. The generation plan includes:

a. Existing Generation b. Future Generation Plans (Projects under

construction and future projects) c. Year-wise capacity addition plan from

renewable source (separately for Solar, and Small Hydro Power (SHP) etc.)

d. Generation capacity required to meet Peak Demand

e. Action plan of the state f. Fund Requirements g. GoI/ State Govt. Interventions

Existing Generation Capacity / Availability of Power (as on 31.03.15) Total generation capacity / availability of power as on 31.03.2015 for the state of Nagaland is 144.02 MW. Out of total 144.02 MW, 39.93 % is from Hydro, 16.66 % is from Coal based Thermal, 23.91 % is from Gas Based Thermal and balance 19.50 % is from Renewable Energy Sources. In terms of ownership, the Central Sector has the largest share of 80.50 %, remaining 19.50 % is the share of State Sector. The details of existing generating capacity available for the state of Nagaland are shown in Table 5.1 below:

Table 5.1

Existing Generation Capacity/ Availability of Power (as on 31.03.15)

Ownership/

Sector Mode-wise Breakup (MW)

Thermal Nuclear Hydro RES Grand Total (MW) Coal Gas Diesel Total

State 0.00 0.00 0.00 0.00 0.00 0.00 28.09 28.09

Private/ IPPs 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Central 24.00 34.43 0.00 58.43 0.00 57.50 0.00 117.37

Total 24.00 34.43 0.00 58.43 0.00 57.50 28.09 144.02

Future plan for augmentation of generation capacity / availability of power As per generation plan of State of Nagaland, capacity of around 157.25 MW is expected to be added by FY 2018-19 (from new projects as well as from allocation from Central Sector and IPP Projects). Out of which, 72.25 MW shall be added through non-conventional energy sources and balance 85.00 MW through conventional

sources. As such the total available capacity by FY2018 -19 is expected to be 301.27 MW (200.93 MW– conventional and 100.34 MW – Non Conventional). Year wise Summary of Generation Capacity / availability of Power, upto FY 2018-19 is indicated in Table-5.2 below:

CHAPTER – 5: GENERATION PLAN


Table 5.2 Year wise Existing & Likely Capacity to be added (MW)-Cumulative

Sl. No.

Particulars Year wise Existing & Likely Capacity to be added (MW)-Cumulative

As on March 2015

FY 2015-16

FY 2016-17

FY 2017-18

FY 2018-19

A. State Sector a. Thermal 0.00 0.00 0.00 0.00 0.00 b. Hydro 0.00 0.00 0.00 0.00 0.00 c. RES (MNRE) 28.09 30.19 30.64 32.74 40.34

B. Private/IPPs a. Thermal 0.00 0.00 0.00 0.00 0.00 b. Hydro 0.00 0.00 0.00 0.00 0.00 c. RES (MNRE) 0.00 0.00 20.00 60.00 60.00

C. Central Generating Station a. Thermal 58.43 103.43 103.43 103.43 103.43

b. Hydro 57.50 57.50 77.50 97.50 97.50 c. RES (MNRE) 0.00 0.00 0.00 0.00 0.00

Total 144.02 191.12 231.57 293.67 301.27 Break up & details of capacities likely to be added year wise is indicated in Annexure– IV.

Future Projects

Government of Nagaland (GoN) has proposed implementation of following Hydro Electric Projects likely to be commissioned after FY 2018–19 to meet the future power requirement of the state.

• Zungki HEP 24MW, • Lower Tizu HEP 36 MW, • Tizu Valley HEP 15MW

100% Fund requirement (State Share) for the above projects is expected to be borne by GOI.

Peaking & Energy Availability to Meet Peak & Energy Demand

Year wise peaking power availability has been worked out based on the peaking availability & auxiliary power consumption norms of each plant as per National Electricity Plan (Vol-I) for 12th five year Plan.Energy availability has been

worked-out considering the actual PLF of State generating station, as intimated by the State. For central hydro power plants, energy availability has been worked out by the PLF indicated by CEA. However, as per information provided by the State, the possibility of installation of Solar Power Projects by IPPs in the State does not appear very encouraging due to remote location of this North East State of Nagaland. As such, contribution from Solar Projects, both in Peak Availability and Energy Availability does not seem certain and has not been considered in projection of Peak and Energy Availability. Similarly the energy availability in each year has also been worked out based on the PLF & auxiliary power consumption norms of each plant as per National Electricity Plan and as per the state information. The availability of peaking capacity and energy availability have been worked out up to FY 2018-19 and shown in Table 5.3 below:

Table 5.3 Peaking and Energy Availability up to FY 2018-19

Sl. No.

Particulars FY

2015-16 FY

2016-17 FY

2017-18 FY

2018-19 1 Total Capacity (MW) 191.12 231.57 293.67 301.27 2 Estimated Peak Availability at State Periphery (MW) 154.52 171.68 190.28 196.88 3 Estimated Energy

Availability at State Periphery

Energy from all sources (MU) 707.36 902.06 957.90 977.74 Energy from renewable sources (MU)

94.11 98.18 103.66 123.50


Based on the deliberation in the previous text, the scenario in the state emerges as shown in the Table-5.4a below.

It could be seen from Table 5.4a that the peak demand of Nagaland would be about 265.00 MW by FY 2018-19 considering the additional power requirement for providing 24x7 power supply to all in the state. The expected energy requirement at state periphery for FY 2015–16 is 747.53 MUs which is likely to increase to 1169.72 MUs by FY 2018-19. It is also observed from Table 5.4a that the state will have a deficit of about 6.13% to 34.60% in terms of Peak

demand during the period FY 2015-16 to FY 2018-19. In terms of availability of energy also, the state will face deficit in the range of 5.68% to 19.64% for the FY 2015-16 to FY 2018 – 19 except during FY 2016-17 when the state will have surplus energy availability to the tune of 1.20%. Therefore, Nagaland State will remain as power deficit state during the period( i.e. from FY 2015-16 to FY 2018-19) having deficit in both peak power and energy availability with the exception of FY 2016 – 17in which the State will have energy surplus

Table-5.4a Sl. No.

Power Supply Position Unit Year wise Figures

FY 2015-16 FY 2016-17 FY 2017-18 FY 2018-19

1 Estimated Peak Requirement at state periphery

MW 164.00 198.00 235.00 265.00

2 Estimated Availability of Peak/ Maximum Demand at state periphery as per State Generation Plan

MW 154.52 171.68 190.28 196.88

3 Peak Surplus (+)/Deficit(-) MW -9.48 -26.32 -44.72 -68.12

4 Surplus(+)/Deficit(-) % -6.13% -15.33% -23.50% -34.60%

5 Estimated Energy Requirement at State Periphery

MU 747.53 891.19 1048.15 1169.72

6 Estimated Energy Availability at State Periphery as per State Generation Plan

MU 707.36 902.06 957.90 977.74

7 Energy Surplus (+)/ Deficit(-) MU -40.17 10.87 -90.25 -191.98 8 Energy Surplus (+)/ Deficit(-) % -5.68% 1.20% -9.42% -19.64%

As the state generation is heavily dependent on hydro (about 30% to 40% during the study period), the above deficit energy scenario may change on year to year basis depending upon monsoon scenario in the state. However, it is expected that the State of Nagaland still will be an energy deficit state for the period FY 2015-16 to FY 2018-19. In poor monsoon years, the deficit of energy is expected to be more due to less generation from hydro power projects. On the other hand, in the years of above-average / good monsoon scenario, the contribution of hydro power projects is expected to be higher resulting in improvement in the scenario.

As deliberated above, the State of Nagaland is expected to be an energy deficit state during the entire period of study. In order to mitigate the above situation, Government of Nagaland would have to effectively plan through comprehensive power procurement initiatives on short term, medium term & long term basis and look for procurement of power either through competitive bidding or through other sources such as enhanced allocation from CGS. Further, the peak demand and energy requirement of the State can also be effectively reduced through proper implementation of DSM & Energy efficiency measures in the state. The generation mix as per the proposed generation plan of the state is shown in Table- 5.4b.


Table -5.4b

Generation Mix

Sl. No. Description FY 2014-15 FY 2015-16 FY 2016-17 FY 2017-18 FY 2018-19

a. Thermal 40.57% 54.12% 44.66% 35.22% 34.33% b. Hydro 39.93% 30.09% 33.47% 33.20% 32.36% c. RES (MNRE) 19.50% 15.80% 21.87% 31.58% 33.31%

ACTION PLAN – STATE

To complete the generating capacities of State and to monitor the Central Sector & Private sector Projects as per following Roll out Plan given in Table- 5.5:

Table -5.5

Sl. No. Power For All (Roll Out Plan)

Year wise Addition (MW) Total (MW)

FY 2015-16 FY 2016-17 FY 2017-18 FY 2018-19 A. State Sector

a. Thermal 0.00 0.00 0.00 0.00 0.00 b. Hydro 0.00 0.00 0.00 0.00 0.00 c. RES (MNRE) 2.10 0.45 2.10 7.60 12.25

B. Private/IPPs a. Thermal 0.00 0.00 0.00 0.00 0.00 b. Hydro 0.00 0.00 0.00 0.00 0.00 c. RES (MNRE) 0.00 20.00 40.00 0.00 60.00

C. Central Generating Station a. Thermal 45.00 0.00 0.00 0.00 45.00 b. Hydro 0.00 20.00 20.00 0.00 40.00 c. RES (MNRE) 0.00 0.00 0.00 0.00 0.00

Total 47.10 40.45 62.10 7.60 157.25

The state is required:

To firm up plan to reduce the peak demand and energy demand through demand side management (DSM) and by adopting energy efficiency measures.

As a medium term measure, to procure cheaper power under case-I route from the market to meet the demandfor providing 24x7 power in the state.

As a long term measure, to take the matter with MoP, GoI for more allocation from Central Sector Projects to Nagaland for meeting the power demand of the State.

To take up the matter of fund requirement with GOI for execution of hydro projects to be developed by the state so that no viable identified resourceswithin the state remain untapped.

POWER PURCHASE PLANNING

The state will work towards institutionalizing and strengthening the Power Purchase Planning and Procurement Cell, which will dedicatedly work on the short / medium / long term power purchase planning and work on the procurement of power on cost effective basis.

This cell will also work on the monthly power availability from already tied up sources (on the basis of annual schedules provided by these sources) and accordingly work out the requirement for tying up power through competitive bidding route or allocation from Central Generating Station keeping into consideration variation in availability & requirement of energy from various sources across the year.


Government of India (GOI) Intervention Required:

State of Nagaland may be considered for enhanced allocation of power from the CGS.

GoI is requested for 100 % funding for the upcoming state sector projects, So that state dependency on the Central sector projects gets reduced.

Fund Requirement

The details of estimated fund requirement of the state sector projects are given in the Table 5.6 below:

Table -5.6

For State Sector/JV Projects (Rs. in Cr.)

Sl. No.

Particulars Total Cost of Project (crores)

Expenditure up to March 2015

Year wise Fund Requirement (Rs in Crores)

Details of Fund arrangement

FY 2015-16

FY 2016-17

FY 2017-18

FY 2018-19

A State Owned Projects 1. Future Hydro

Projects under consideration (Zungki 24MW, Lower Tizu, 36 MW, TizuVally 15MW)

768.00 - 65.00 230.00 300.00 133.00 Proposed for 100% funding by GoI

2. Hydro Electric Projects under R & M (Tsutha 0.75MW, Duilimroi 0.54MW, Dzuza 1.5MW and Telangsao 0.6 MW)

30.38 - 8.00 10.00 10.00 2.38 Proposed for 100% funding by GoI

3. State owned Small Hydro Projects

164.63 16.11 16.74 39.09 43.00 49.69 Funding: 102.37 Crores from MNRE and balance from NEC and Ministry of DONER, GOI

Total (State Share)

963.01 16.11 89.74 279.09 353.00 185.07

Note : Projects mentioned under Sl. No. 1 and 2 are expected to be completed / commissioned after FY 2018-19.


The present peak power demand and energy requirement for the State of Nagaland is of the order of 145 MW and 721.14 MU (for FY 2014-15). The Power demand in the coming years would increase significantly due to various factors i.e. increase in demand of existing consumers due to increased uses of various appliances, commercial activities and industrialization etc. in the State. Considering all the above factors into account and with an objective to provide 24x7 power supply to all, the expected power demand of Nagaland by FY 2018-19 would be in the order of 265.00 MW with annual energy consumption of 1169.72 MU. To meet this growing demand, a robust and reliable Inter-State & Intra-State transmission network is required. For this, existing transmission system would be strengthened

both at Inter State level as well as Intra State level with proper planning to cater the demand in a reliable manner considering 24X7 Power for All. Inter State Transmission System (ISTS)

Presently about 727ckt km EHV transmission line comprising of 220 kV (348ckt km),132 kV (508.81ckt km) and 02 nos. of Grid sub-stations (220/132 kV Sub-station) with total transformation capacity of 260 MVA are existing in Nagaland under Inter-State Transmission system.

The existing Inter-State Transmission capacity at 220/132 kV level is 260 MVA consisting of 2 nos. of Substations. The details of existing ISTS Sub-stations in Nagaland are as under:

Table-6.1 Details of Existing Grid sub-station (ISTS)

Sl.

No. Name of GSS Voltage Ratio No. of

Transformers MVA

capacity Total Transformer

capacity(MVA) 220/132 kV GRID SUBSTATION

1. Dimapur 220/132 kV 2 100 200 2. Mokokchung 220/132 kV 1 60 60

Total 260 Source: State Power Utilities

In order to facilitate the drawl of power by Nagaland and to meet the projected peak load of 265.00 MW by FY 2018-19, some modifications to Inter-State transmission system (ISTS) has been planned.

The various planned ISTS projects are outlined below. :

New Substation &Transmission lines at 220 kV level

• One no. 120 MVA 220 kV Grid Substation having 100 MVA & 20 MVA installed capacity at 220/132 kV & 132/33 kV level respectively is under construction at Zhadima (Kohima) under the ownership of Deptt. of Power Nagaland (DOPN).

• One no. 220kV D/C line (69 Km) is under construction from Dimapur to Zhadima.

• One no. 220 kV S/C line (92 Km) is planned from MKG PGCIL to New Kohima.

Addition of Transmission Line Bay in existing sub-stations

To meet the growing power demand of Nagaland, addition of New Line Bay has been undertaken as follows:

• Augmentation of 220 kV Mokokchung PGCIL.

• Addition of 220 kV Line Bay at Mokokchung PGCIL.

Future Tariff based Competitive Bidding (TBCB) Schemes. (NERSS – VI)

• Imphal to New Kohima 400 kV D/C 240 CKm Transmission Line.

• New Kohima to New Mariani 400 kV D/C 220 CKm Transmission Line.

• Setting up of 400/220 kV 2X500 MVA Substation at New Kohima.

CHAPTER – 6: TRANSMISSION PLAN


Adequacy to meet Power Transfer requirement of the State till FY 2018-19

The present ISTS system capacity at 220 kV CTU level is 260 MVA in the state of Nagaland. This shall be increased to 360 MVA (including DOPN capacity addition of 100 MVA at 220kV) by FY 2016-17 after implementation of ongoing schemes to cater the peak power demand of Nagaland of 265.00 MW by FY 2018-19.

The net power to be evacuated from the above units at 132 kV level & below is 35.90 MW (40 MVA) in FY 2015-16, 36.29 MW (40.3 MVA) in FY 2016-17, 38.12 MW (42.4 MVA) in FY 2017-

18 & 44.72 MW (50 MVA) in FY 2018-19. The projected power demand of Nagaland by FY 2018-19 shall be 265.00 MW (295 MVA). Considering drawl of about 44.72 MW (50 MVA) of power from the state generating units at 132 kV and below, the balance power to be evacuated at 220 kV level shall be 220.28 MW (245 MVA) by FY 2018-19. Considering 80% loading on transformers and overall diversity of 1.2, minimum transformation capacity required is 1.5 times the projected peak demand (MVA) i.e. 367 MVA (=1.5 X 245 MVA).

The year wise generation addition, total available capacity vis-a-vis transmission system available at 132 kV level for Nagaland is tabulated as under:

Table-6.2

Year Generation Within Nagaland

– Intra state (MW)

Inter state (ISGS) – Generation for

Nagaland (MW)

Total Available capacity

(MW)

Peak Power Demand of

Nagaland to be evacuated at 220kV level (Peak power demand - Power

evacuated at 132 kV level and below.)

( MW)

Minimum Transform

ation capacity required at 220kV

level ( MVA)*

Transmission System

existing/Planned at 220 kV level

including PGCIL & DOPN

(Interstate &Intrastate)

220 kV GRID S/S (MVA)

Addition Total Addition Total As on

Oct 2015 41.57 102.45 144.02

FY 2015-16 2.10 43.67 45.00 147.45 191.12 164.00 – 35.90 =

128.10 214 260

FY 2016-17 20.45 64.12 20.00 167.45 231.57 198.00 – 36.29 =

161.71 270 360

FY 2017-18 42.10 106.22 20.00 187.45 293.67 235.00 – 38.12 =

196.88 328 360

FY 2018-19 7.60 113.82 0.00 187.45 301.27 265.00 – 44.72 =

220.28 367 360

* Minimum Transformer capacity in MVA = Peak Power Demand at distribution level (in MW/0.9 x 1.5).

As such it is evident from the above table; the existing and planned ISTS System is just adequate to meet the projected peak demand of Nagaland up to FY 2018-19.

Action Plan – CTU

• Ongoing schemes (New Substation & Transmission line) shall be implemented as per schedule by PGCIL/TBCB route for ensuring the transmission system to achieve the target of 24 X 7.

• To achieve the target, expansion and augmentation of Transmission facility need to be done with sustainability. Due thrust may be given for proper implementation of ESPPF (Environmental & Social policy and Procedures Framework), which has been designed to identify, address and mitigate any adverse environmental & social issues during project implementation.


Action Plan – GOI

The GOI has undertaken up a transformative change programme in the power sector so as to ensure affordable 24x7 power for all homes, industrial and commercial establishments and adequate power for all, in the next few years.

• Wherever necessary, clearances (Highway, forest clearance etc.) as required shall be expedited at the highest level for timely completion of the project.

• Adequate attention shall be paid to funding of Augmentation of Zhadima 220 kV Substation along with associated lines, so that capacity addition may be completed within the stipulated time period.

Intra State Transmission System:

The existing Intra state transmission capacity is as follows:

• 132/66 kV level =180MVA. • 132/33 kV level =46.5MVA. • 66/33 kV level = 170 MVA.

The ongoing strengthening program of existing Intra-State transmission system is under implementation up to FY 2018-19. After implementation of this plan, the existing transformation capacity at 132/33 kV level shall increase to 470.5 MVA.

The installed capacity pertaining to 132/66 kV & 66/33 kV shall remain unchanged.

Intra State Transmission System (Present):

The transmission network comprising of 19 substations (Oct 2015) of various voltage levels presently caters to the load demand across the State.

• 1 No. of 132 kV grid substation at Nagarjan (Dimapur) having 100 MVA & 60 MVA installed capacity at 132/66 kV & 66/33 kV level respectively and 76.3 km of associated lines.

• 2 Nos. of 132 grid substations at Aolichen (Mokokchung) having 50 MVA & 15 MVA installed capacity at 132/66 kV and 66/33

kV level respectively & at Kiphire having 30 MVA & 5 MVA installed capacity at 132/66 kV and 66/33 kV level respectively and 274.62ckm of associated lines.

• 1 No. of 132 kV grid substation at Kohima having 24 MVA installed capacity at 132/33 kV level and 180.33ckm of associated lines.

• 2 Nos. of 132/33 kV grid substations at Wokha & Meluri (Phek) with 10 MVA & 12.5 MVA substation installed capacity respectively and 69ckm of associated lines.

• 13 Nos. of 66 kV grid substation at Dairy

Farm, Nito farm, Ganesh Nagar, Chumukedima, Sovima, Powerhouse (Dimapur), Tuli (Mokokchung), Naginimora, Mon, Tizit (Mon), Tuensang & Zunheboto with 166.6 MVA substation installed capacity and 264.77 km of associated lines.

Note: List of existing 132 kV & 66 kV substations and transmission lines is enclosed as Annexure-V.

Details of Ongoing / Planned Intra-State Transmission system.

New Substation &Transmission lines • 12 Nos. of 132/33 kV substations at Kohima,

Zhadima, Zhadima (Chiephobozou), NH61 (Philimi), Doyang, Rangapahar, Wokha, Longnak, Longleng, Zunheboto, Secratariat complex (Kohima) & Pfutsero (Phek) with 424 MVA capacity and 416.08 km transmission lines are planned for implementation during FY 2018-19.

• 1 Nos. of 132/11 kV grid substation at Razaphema Green field Airport with 12.5 MVA capacity and 13.4 km transmission lines is planned for implementation up toFY 2018-19.

• 1 No. of 66/11 kV grid substations at Cricket Stadium Sovima (Diampur) with 20 MVA capacity and 55 km transmission lines is planned for implementation up to FY 2018-19.


The year wise proposed plan of new sub-station and Transmission lines are as follows: Table-6.3

Project Voltage Level

Unit FY 2015-16

FY 2016-17

FY 2017-18

FY 2018-19

Intra-State Trans-mission Network

132/33 kV No./MVA 1/24 4/55 - 7/345 ckt. km. 84.6 20.77 48.71 262

132/11kV No./MVA - - - 1/12.5 ckt. km. - - - 13.4

66/11 kV No./MVA 1/20 - - - ckt. km. 55 - - -

Augmentation on existing sub-stations

• 7Nos. of Substations are undergoing augmentation at 220, 132 & 33 kV levels in the form of Bay extension to accommodate New Lines.

The details of year wise ongoing/ planned Intra-State transmission system as enclosed as Annexure-VI.

Adequacy to meet Power Transfer requirement of the state till FY 2018-19

The year wise peak power demand of State, vis-a-vis transmission system available at 132 kV level for Nagaland is tabulated as under:

Table- 6.4

* Minimum Transformer capacity in MVA = Peak Power Demand at distribution level (in MW/0.9 x 1.5). ** Projected Transmission Capacity based on planning. As such, the existing Intra-state transmission system of Nagaland is adequate to meet the projected peak demand of Nagaland of 265.00 MW by FY 2018-19 both at 132 kV level as well as downstream level.

Year wise fund requirement for development of Planned Transmission system

Total estimated investment of about Rs. 388.94

Crores from FY 2015-16 to FY 2018-19 has been envisaged for intra State system excluding NERPSIP funding.

(Details of year wise investment plan for transmission infrastructure for FY 2015-16 to FY 2018-19is enclosed as Annexure –VI.

Year Peak power demand (MW)

Minimum Transformation capacity required (MVA) *

Transmission System existing/Planned at 132/33 kV (MVA)**

Addition Total Addition Total

As on Oct 2015 120 200 396.5

FY 2015-16 44 164 274 24.0 420.5

FY 2016-17 29 198 330 55.0 475.5

FY 2017-18 33 235 392 0.00 475.5

FY 2018-19 39 265 442 345.0 820.5


Year wise details of Physical targets and proposed investments Details of tentative investment plan for FY 2015-16 to FY 2018-19 are as below:

Action Plan – DOPN (STU)

The ongoing scheme needs to be implemented as per proposed plan for ensuring 24x7 power supply in State. Financial tie up for approved infrastructure shall be undertaken timely with the funding agencies.

State Government intervention

• The proposed transmission system up to FY 2018-19 needs to be implemented as per schedule for ensuring 24x7 power supply in the State.

• The State government shall expedite all necessary help (i.e. Right of Way clearance, Forest clearance if any, land acquisition etc) to STU for installation of new substation and associated transmission lines to provide 24x7 power to all in Nagaland.

• Investment of about Rs.388.94 Crores from FY 2014-15 to FY 2018-19 has been envisaged for intrastate transmission system. Financial tie up with financial institutions regarding fresh proposals for transmission infrastructure should be looked into for effective implementation.

• State needs to make adequate budgetary provision towards building transmission infrastructure and eliminating bottlenecks. As an illustration, the following case may be cited. A new 132/33 kV proposed at Rangapahar, which will receive power from Dimapur 132 kV GSS at 132 kV level.

Rangapahar shall in turn feed the existing 33/11 kV substations which will cater the load of Dimapur town. Hence sanctioning of this 132 kV Substation along with necessary 132 kV line has become absolute necessary in view of providing supply to increasing load of Dimapur town.

Government of India intervention

• Mitigation of Right of way constraints and availability of land: GoI, MoP has issued guidelines on 15th October’ 2015 on providing compensation for acquiring Right of way for Transmission Line.

• Upgrading of existing transmission lines with high capacity conductor to meet reliability criteria. It will involve high costs. Intervention at the level of Government of India needed.

• Adoption of the GIS technology at new substations specifically in the urban area having land scarcity and Government of India intervention for cost reduction of Gas Insulated Substation (GIS) technology is required.

Initiatives taken by the State on SCADA and OPGW State Load Despatch Centre (SLDC) is functioning at Dimapur. The SLDC has Optical fibre based communication links with NERLDC. PLCC is available at Substations and Generating Stations for communication with SLDC.

0 50 100 150 200

FY 2015-16

FY 2016-17

FY 2017-18

FY 2018-19

Investment in Rs. Cr.

Total Transmission Cost in Rs. Crores


Existing Communication in the Department

• VHF Wireless Communication System:-

• The Department have a dedicated VHF Wireless Communication System linking all the important Sub-Stations, Project Site and Offices, operational since 1988-89 having three spot Frequency allotted to the Department by WPC (DOT), Govt. of India. The VHF Wireless sets was upgraded in 2006 with newer Version of VHF Wireless sets of M/s MOTOROLA for 44 Fixed Stations and 12 Mobile Sets and 74 handheld sets for the whole state coverage with three repeater stations.

• PLCC (Power Line Carrier Communication) :

The Department had interstate PLCC link between Mariani Sub-Station (Assam) – 132 KV Sub-Station Dimapur - Imphal – Lothak HEP (Manipur) for speech Communication with Private Exchange at 132 KV Sub-Station at Nagarjan, Dimapur in early 80’s which is now defunct.

The Department has also installed PLCC (Power Line Carrier Communication) system at 9 (nine) major Sub-stations in 2003 for Speech & Data Communication at namely:

Dimapur (132 kV)

Doyang (132 kV)

Kiphire (132 kV)

Kohima (132 kV)

Mokokchung (132 kV)

Tuensang (66 kV)

Wokha (132 kV)

Meluri (132 kV)

Likim Ro (66 kV)

Three numbers of RTU (Remote terminal unit) were installed under ULDC Project for Data acquisition and monitoring of system parameters at 132 KV S/s Dimapur, 132 KV S/s Kohima & 132 KV S/s Mokokchung. Upcoming Communication proposal / project of the Department:-

• Under the Scheme of GoI for providing

reliable Telecommunication at 33KV, 66 KV & 132 KV Voltage level Sub-stations in all states / UTs. The Department has proposed for OPGW ( Optical Power line Ground Wire ) link for all the 132 KV and 66 KV Transmission line for Data and Speech Communications and V-SAT link for all the manned 29 Nos. of 33 KV Sub-stations with one Data center for Nagaland. This is under consideration by MOP.

Fully fledged facility of SLDC is under at Dimapur as per the DPR prepared by PGCIL. The expected date of functioning is March 2016. The state has funded the civil construction portion while PGCIL has funded the communication equipments to be installed in SLDC.


Distribution system of Nagaland State is being served by The Department of Power Nagaland (DOPN). The Department is serving about 2.55 lakhs of electricity consumers including about 0.12 lakhs under commercial category during FY 2014-15.

As per Government of Nagaland (GoN), as on 1st April 2015 there are about 4.36 lakhs households in the state (2.93 lakhs are in rural area and 1.43 lakhs are in urban area). Out of total 4.36 lakhs households, about 2.95 lakhs households are electrified (1.77 lakhs are in rural area and 1.18 lakhs are in urban area). The reasons underlying the fact that the number of electrified households is more than the number of consumers may be – (i) The electricity consumers as mentioned here are billed consumers. There are many unbilled consumers who are not reflected in the above statistics. (ii) Several single point supplies exist in Nagaland whereby one consumer having single meter provides supply to several other consumers. (iii) Colony communitization has occurred in Mokokchung & Dimapur Districts wherein, the outgoing feeder from Distribution Transformer has a single meter but it supplies multiple consumers. There are still around 1.16 lakhs un-electrified households in the rural areas and 0.24 lakhs un-electrified households in the Urban area as on 1st April 2015.

As on Oct. 2015, daily electricity for about 08 hours on an average is being provided in the rural areas and 18 hours on an average is being provided in the Kohima & Dimapur. The hours of supply depends on availability only. However there is no stipulation in this regard in the State Power Policy, which is in a Drafting stage and may be finalized in 2015-16.

The DT failure rate for DOPN is 9.63 % for FY 2014-15. During the period between FY 2012-13 and FY 2014-15, the HT to LT ratio has increased from 1.06 to 1.12.

Existing Distribution system as on 31st March 2015

There are 105 Nos. of Power Sub-Stations (consisting of 66/11kV & 33/11kV), 3937 Nos. of Distribution Transformers, 3,391.10 cktkms of low tension lines, 3,808.10 cktkms of 11 kV lines and 1,497.20 cktkms of 33 kV lines in the state of Nagaland.

The total installed capacity of HT Power Transformers (consisting of 66/11 kV & 33/11 kV Transformers) and Distribution Transformers (DTs) is 264.10 MVA and 354.97 MVA respectively. The details of distribution system as on 31st March 2015 are indicated in Table-7.1 below:

Table-7.1

Distribution System Details of Deptt. of Power Nagaland (DOPN) as on 31.03.2015

Sl. No. Description Unit DOPN

1. Total Length of 33 kV line Cktkms 1497.20

2. Total Numbers of 66/11kV& 33/11kV Power Sub‐stations

Nos 105

3 Total Capacity of 66/11kV & 33/11kV Power Sub‐stations

MVA 264.10

4. Total Numbers of DTs Nos 3937

5. Total Capacity of DTs MVA 354.97

6. Total Length of 11 kV line Cktkms 3808.10

7. Total Length of LT line Cktkms 3391.10

Source: DOPN

CHAPTER – 7 : DISTRIBUTION PLAN


Category Wise Consumers The number of consumers (category wise) as on 31.03.2015 is shown below:

STATUS OF ON-GOING DISTRIBUTION SCHEMES IN THE STATE

RAPDRP Ministry of Power, Govt. of India, has launched the Restructured Accelerated Power Development and Reforms Program (R-APDRP) in the XIth Five Year Plan as a Central Sector Scheme to cover urban areas - towns and cities with population of more than 30,000 as per Census of 2001. Power Finance Corporation Limited (PFC) has been designated by GoI as the Nodal Agency for the program. The continuation of RAPDRP for 12th& 13th plan has been subsumed in the newly launched IPDS scheme in Dec 2014.The focus of the R-APDRP programme was on actual, demonstrable performance in terms of sustained loss reduction. Establishment of reliable and automated systems for sustained collection of accurate base line data and adoption of Information Technology in the areas of energy accounting will be essential before taking up the regular distribution strengthening projects.

The programme was divided into two (2) parts Part - A and Part - B. Part - A included projects

for establishment of baseline data and IT applications like Meter Data Acquisition, Meter Reading, Billing, Collections, GIS, MIS, Energy Audit, New Connections, Disconnections, Customer Care Services, Web self-service, etc. & verification of baseline AT&C losses as well as implementation of SCADA/DMS (Supervisory Control And Data Acquisition/Distribution Management System). Part-B of RAPDRP included regular distribution strengthening projects i.e. renovation, modernization and strengthening of 11kV lines and substations, Re-conductoring of lines at 11kV level and below, Load Bifurcation, Feeder Separation, Load Balancing, HVDS (11kV), Aerial Bunched Conductor in dense areas, replacement of electromagnetic energy meters with tamper proof electronic meters, installation of capacitor banks & mobile service centers, etc. 100% grant is provided under R-APDRP Part-A projects, while a maximum of 50% grant is being provided for Part B projects after fulfilling certain conditions.

237946

12064

1986 610

2451

1 Domestic

2 Commercial

3 LT Industrial

4 HT Bulk

5 Others


Status of R-APDRP Part-A IT implementation agency was appointed for implementation of R-APDRP-A scheme in 9 towns (with population of more than 15000 which is a special consideration for Nagaland) of Nagaland including establishment of centralized data centre at Guwahati, Customer Care Centre including payment kiosk at Burma camp, Near Police Point, Dimapur, Nagaland, and Centralized Data Recovery Centre at Assam Power Distribution Company Ltd., Dwarandhar, 6th mile, Near Flyover, Guwahati Assam. The scope covered setting of IT infrastructure at DC & DR subdivision offices and other offices and integration of all the offices with data centre by providing suitable connectivity. Facility Management Services for 5 years after “Go-Live” of the projects have also been kept under scope of ITIA. IT Implementation has been done in the following areas;

1. Metering, Billing & Collection processes. 2. New connection, disconnection,

reconnection processes. 3. Generation of exception reports from the R-

APDRP solution. 4. Generation of Energy Audit reports from the

R-APDRP Solution. 5. GIS based consumer indexing and asset

Mapping. 6. GIS based Integrated Network Analysis

Module. 7. Centralized Customer care services. 8. Management Information System (Data

Warehouse). 9. Asset Management and Maintenance

Management. 10. Web Based Self Service Portal. 11. Identify and Assess Management System. 12. System Security requirement. 13. Development of Commercial Data Base of

consumers. 14. The extension for RAPDRP Part-A has been

given by PFC till June 2016.

Highlights of Part-A in the state of Nagaland are: • The scheme was sanctioned in April 2010.

• The amount sanctioned by PFC is Rs. 34.58 Cr. The sanctioned cost has a provision of Rs. 3.43 Cr against the original proposal of Rs. 19.62 Cr for Ring fencing and Metering of system.

• Data Centre completed and commissioned at Guwahati.

• Disaster Recovery Centre completed at Tripura.

• Customer Care Center proposed in Dimapur is under implementation.

• 1296 Nos. DT meters have been installed out of total 1338 Nos.

• Consumer indexing is completed in 6 towns out of 9 towns.

• Asset Mapping is completed in all towns. • The extension for RAPDRP Part-A has been

given by PFC till June 2016.

STATUS OF RGGVY 12th Plan

Government of India launched RGGVY scheme during 10thplan period for providing access to electricity to all rural households in the country. The scheme was continued during 11th Plan and during continuation in 12th& 13th plans, the RGGVY scheme has been subsumed in Dec. 2014 in the newly launched DDUGJY scheme of GOI. Under this scheme, 90% grant was provided for electrification of un-electrified Households, intensification of partially electrified households and free electricity connections to BPL households in the country. The project cost for RGGVY 12th Plan is Rs. 87.46 Cr. The Roll out plan of DOPN shows an allocation of Rs. 36.55 Cr. in FY 2015-16 & Rs. 50.91 Cr. in FY 2016-17. However, REC has till date released Rs. 26.54 Cr. in October to this effect.

LOA for the job has been awarded on turnkey basis on 29.11.2014. NORTH EASTERN REGION POWER SYSTEM IMPROVEMENT PROJECT (NERPSIP) UNDER WORLD BANK FUNDING

The project cost is Rs. 106.75 Cr. The Roll out plan shows an allocation of Rs. 56.47 Cr. in FY 2016-17 & Rs. 50.28 Cr. in FY 2017-18. M/s


PGCIL has already floated the NIT for the Work. The work includes construction of new 33/11 kV Substations (10 nos.), Augmentation work in existing 12 nos. Sub-stations, 7 No. new 33 kV Bay, 76.5 Km of New 33 kV lines and laying of 233.5 Km of Optical Ground wire in the State. STATUS OF DDUGJY

The project cost is Rs. 40.27 Cr. The Roll out plan of DOPN shows an allocation of Rs. 12.49 Cr. in FY 2015-16 & Rs. 27.78 Cr. in FY 2016-17. The work shall be executed departmentally. Site Survey is now under progress by the Department.

The summary of overall plan against ongoing projects is as under:

Under 12th Plan RGGVY Scheme, an amount of Rs. 6.57 Crs. has been sanctioned towards commissioning of New S/s and capacity Augmentation works in existing S/s, Rs. 36.47 Crs. towards laying of New HT line/feeders, Rs. 12.43 Crs. towards installation of New DTRs and Rs. 31.98 Crs for works related to laying of LT Line and providing Service connection to BPL consumers.

Under DDUGJY Scheme an amount of Rs. 23.54 Crs. has been sanctioned towards works related to Laying of New HT line/feeders, Rs. 4.64 Crs. towards Installation of New DTRs and Rs, 12.09 Crs. towards works related to laying of LT Line and providing Service connection to BPL consumers.

Under NERPSIP DMS Scheme an amount of Rs. 3.99 Crs. has been sanctioned towards works related to laying of New 33 kV Line/Feeders, Rs. 78.29 Crs. towards commissioning of New S/s and capacity Augmentation works in existing S/s, Rs. 16.71 Crs. towards laying of New HT line/feeders and Rs, 7.76 Crs. towards laying of OPGW/ADSS.

Proposed Government of India Schemes-

Deen Dayal Upadhyaya Gram Jyoti Yojana (DDUGJY)

Government of India launched Deendayal Upadhyay Gram Jyoti Yojana (DDUGJY) on 3rd December, 2014 for;

(i) Strengthening and augmentation of sub-transmission & distribution infrastructure in rural areas, including metering of distribution transformers/ feeders/ consumers.

(ii) Rural electrification for completion of the targets laid down under RGGVY for 12th and 13th Plans by carrying forward the approved outlay for RGGVY to DDUGJY.

The components at (i) of the above schemes will have an estimated outlay of Rs. 43033 Crores including a budgetary support of Rs. 33453 Crores from Government of India during the entire implementation period.

As already mentioned, the scheme of RGGVY as approved by CCEA for continuation in 12th and 13th Plans has been subsumed in this scheme as a separate rural electrification component for which CCEA has already approved the scheme cost of Rs. 39275 Crores including a budgetary support of Rs. 35447 Crores. This outlay will be carried forward to the new scheme of DDUGJY in addition to the outlay of Rs.43033 Crores. REC is the nodal agency for the operationalization of DDUGJY in the Country.

The DPR for 11 districts of Nagaland amounting to Rs. 342.21 Cr. has been submitted to REC Limited for Approval. The status for RGGVY (X, XI & XIIth plan) and DDUGJY as on 31.01.2016 shows that an amount of Rs. 280.78 Cr. has been sanctioned against Rs. 402.28 Cr. 102 No. of UE villages have been electrified out of 184 Nos., 1152 No. of Intensive electrification of villages have been carried out of 1949 Nos. and 54559 Nos. of BPL HH connections have been provided out of a total of 93873 Nos. for the state of Nagaland. The state intends to electrify remaining 82 UE villages in a phase wise manner – 42 nos. in FY 2016-17 and 40 nos. in FY 2017-18. An amount of Rs. 42.38 Cr. has been sanctioned for electrification of 81 UE villages under DDUGJY scheme and an amount of 92.31 Cr. has been sanctioned towards electrification of 1 No. UE village along with 797 nos. of villages under Intensive electrification programmme.


Integrated Power Development Scheme (IPDS)

The Central Government has sanctioned “Integrated Power Development Scheme” (IPDS) on 3rd December, 2014 for urban area for: (i) Strengthening of sub-transmission and

distribution networks in the urban areas.

(ii) Metering of distribution transformer/ feeders/ consumers in the urban areas.

(iii) IT enablement of distribution sector and

strengthening of distribution network for completion of the targets laid down under R-APDRP for 12th and 13th Plans by carrying forward the approved outlay for R-APDRP to IPDS.

The components at (i) and (ii) above will have an estimated outlay of Rs. 32,612 Crores including a budgetary support of Rs. 25,354 Crores from Government of India during the entire implementation period.

The scheme of R-APDRP as approved by CCEA for continuation in 12th and 13th Plans has been subsumed in this scheme as a separate component relating to IT enablement of distribution sector and strengthening of distribution network [component (iii) above] for which CCEA has already approved the scheme cost of Rs. 44,011 Crores including a budgetary support of Rs. 22,727 Crores. This outlay will be carried forward to the new scheme of IPDS in addition to the outlay indicated above. PFC is the nodal agency for the operationalization of IPDS in the country.

Against a submitted DPR cost of Rs. 230.33 Cr. for 12 towns of Nagaland, MoP, GoI/PFC has accorded in principle an approval of Rs. 43.92 Cr. only for the 12 towns. The summary of overall plan against future projects is as under:

In IPDS Scheme, an amount of Rs. 117.73 Crs. has been allotted towards Strengthening of Sub-Transmission and Distribution Network, Rs. 62.59 Crs. towards Metering & Rs. 50.00 Crs. towards Installation of Roof Top Solar Panel at

SS. Whereas in DDUGJY Scheme, Rs. 14.12 Crs. has been allotted towards Feeder Separation works, Rs. 265.83 Crs. has been allotted towards Strengthening of Sub-Transmission and Distribution Network & Rs. 62.26 Crs. towards Metering.

Note: Complete detailed scope of work in Rural & urban areas, district wise, are shown in Annexure-VIII to XI.

IT INTIATIVE TAKEN BY DOPN

In accordance with the IPDS guidelines, the state has 19 towns of 5000 and above population as of 2011 census eligible for the schemes out of which 9 (nine) towns are already taken up under RAPDRP- Part (A) and is under implementation.

Following are the technology up-gradation/renovation and modernization schemes being adopted/ proposed to be adopted through RAPDRP- Pt. (A) and the proposed IPDS scheme - the state is targeting the following objectives.

1) AMR based metering technology for all 11KV/33KV Feeders & boundary including DTs and HT consumers.

2) Online system for billing, collection, energy accounting/auditing and IT based Customer care centre (CCC).

3) Introduction Spot billing machine (SBM).

4) Network analysis and voltage regulation through.

a) Re-conductoring of long and overloaded 11KV feeders from existing ACSR Weasel to Raccoon.

b) Construction of high clearance 11KV lines main trunk line along main road/highways incorporating GI SP 76 poles and ACSR hares, with the option of linking with existing and proposed new SSs for relieving overloaded feeders and cater future load growth.

c) LT Line associated with new DTs and re-conductoring of long overloaded LT feeders for improvement of voltage


regulation and reduction of technical losses.

d) Distribution Transformers to cater new load and augment existing overloaded DTs with long LT lines.

5) Introduction of ABC in theft prone areas in Dimapur and Chumukedima towns especially in congested and slum areas. DOPN also contemplates introducing UG cables in New Kohima and in some part of Dimapur.

6) Ring fencing of IPDS towns including additional requirement for 9 RAPDRP towns for completing ring fencing and facilitating full proof online energy audit and account system.

7) Replacement of electromechanical meters with electronic meters in all 19 towns.

8) Introduction of Prepaid meters in 3 major

loads intensive and revenue centres – Dimapur, Kohima and Chumukedima. From the experience of pilot initiative in one area in Dimapur during 2013-14 with 1000 prepaid meters, the State is very confident of reduction of AT & C losses of the state appreciably.

9) Relocation of inaccessible consumer meters

to outside of premises for improving billing.

Communitisation of Electricity management:

Under the Nagaland Communitisation of Public Institutions and Services Act 2002, the Department of Power has so far communitised 1208 villages out of 1452 villages.

a) Electricity Revenue collection from the rural areas has been a long and difficult struggle for DOP.

b) Revenue losses (or Aggregate Technical and Commercial losses) in the rural areas were

very high (60-70%) due to poor billing, collection and nonpayment.

c) The main objective of Communitisation is for curbing theft of energy with community participation and improving billing & collection efficiency.

d) Under communitisation a single electricity bill is served to the VEMBs based on the Single point metering (SPM); Distribution transformer input-based. The VEMBs collect the revenue from the households and pay to the department after deducting 20% as incentives.

e) Training to VEMB members are imparted by DoPN.

On spot extension of load regularization: Load sanction/regularization is accorded on receipt of application and after Feasibility report is received from concerned JE within a fortnight.

Making villages aware of the problems and hearing their grievances:

As mandated by Regulatory commission, CGRF has been set in one of the circle.

Improving HT: LT ratio HVDS is proposed in Dimapur and Chumukedima.

Implementation of IT enabled services for Power consumers

Web based/portal services online system for billing, payment/ collection. Setting up of Customer care centre at Dimapur and providing Toll-free phone line to receive consumer’s complaint and redressal.

Opening of payment counters in Bank premises and tying with Postal service for collection of revenue in remote areas.

Reduction in AT&C Losses

The projected AT & C losses are summarized below in Table 7.8:

Table-7.2

Sl. No. Description FY 2015-16 FY 2016-17 FY 2017-18 FY 2018-19 1 AT&C Loss (%) 54.21 46.71 39.21 31.71 2 T&D Losses (%) 35.98 28.48 20.98 13.48

2.1 Intra State Transmission Loss (%) 3.5 3.5 3.5 3.5 2.2 Distribution Loss (%) 33.66 25.89 18.11 10.34


The reasons for high AT&C Losses in the state are primarily the following: • Deficiency in the organizational setup &

Support from Govt. Power Dept.

• Electricity consumer in the state consists mainly of domestic (90%) and very small segment of industrial consumer (10%). The Dept. is neither structured to function as a commercial Organization nor does it receive adequate financial support from the Govt.

• The Dept is also plagued by shortage of manpower. The billing efficiencies are 53%, 54% and 59% respectively for FY 2012-13, FY 2013-14 & FY2014-15 while the collection efficiencies for the corresponding years are 59.47%, 60.55% & 53.51% respectively. All these factors lead to inefficiency of the power sector by enhancing the AT&C loss figure. Therefore reduction of AT&C Losses from the present alarming 61.71% to 31.71% requires a very committed road map/policy of the Govt by considering electricity as a business commodity for essential contribution towards the growth of the economy (resources) while notwithstanding the social obligation in providing energy as a basic need.

• Defective meter (45%), tampering and power theft are the main causes for high AT&C losses.

• The state is forced to maintain a high HT line length ratio owing to the hilly terrain and sparsely distributed population of the region. This distributed population not only increased the capital investment requirements of the state but also makes the maintenance and monitoring of the network very difficult.

DOPN have envisaged following measures for bringing down AT&C losses;

1. Installation of meters outside the consumer premises.

2. Identification of loss prone area by tagging of consumers with DTs and feeders for energy accounting.

3. Introduction of ABC in theft prone areas in Dimapur and Chumukedima towns especially in congested and slum areas. DOPN also

contemplates introducing UG cables in New Kohima and in some part of Dimapur.

4. Replacement of defective /electro mechanical meters with static meters in 19 towns.

5. Automatic meter reading (AMR) to be implemented for all 11 kV/33 kV feeders and Boundary meters including DTs & HT meters.

6. Officer of the rank of J.E/A.E may be assigned the job of Feeder Manager for monitoring of Feeders and maintaining all the statistics of the feeders assigned to him.

7. Spot settlement of bill dispute and release of new connections: Any bill dispute/complaint are attended/settled at the instant as and when received by concerned SDO/JE except few cases which requires detail investigation/testing of meters.

For domestic category, connection is generally released within the timeline except cases with non-submission of documents, payment of demand note, Test reports, etc. by consumers. For convenience of consumers, 2 (two) days in a week are allotted for release of new connection.

8. Improvement in HT/LT ratio.

9. Formation of Special Task Force for raid against theft: DOPN has set up Anti Power Theft Mobile Squad (APTMS) which comprises of Deptt. officials and Police in three major towns of Dimapur, Chumukedima, and Kohima. Deptt. has plan to set up in all the Districts as well. The Circle/Division organize raid against theft and unauthorised use of electricity on regular basis (twice weekly) through the mobile squad. Further Special police stations and Special courts has been set up and notified to deal with theft of power in the state.

10. Outsourcing of Meter reading and bill delivery in few areas of Kohima & Dimapur.

11. Implementation of IT enabled services for power consumers. This has great potential in reducing losses and providing consumer friendly services.

12. Introduction of modern technologies to monitor reliable and quality power supply:

13. To introduce modern technologies, to monitor & quality supply Proposed for introduction of


Autoreclosures for ease of maintenance and to restore power supply during transient line faults under IPDS. IT will also function to activate operation of sectionalizer and PFIs. During line faults, power outage takes places throughout the area fed by the feeder. On an average it takes 8 hrs to locate and restore the power. Therefore with Sectionalizer faulty sections will be isolated and power supply can be maintained in healthy sections and reduce restoration time. This will ensure stability of power supply and result into commercial gain by increase in billing. For quick location of faults and restoration of power supply. PFIs will function in tandem with Sectionalizers and Autoreclosures at SS.

Under RAPDRP modules such as GIS, Network analysis SAP driven ERP systems are incorporated in the scheme.

14. Introduction of Pre-Paid Meter Pilot Project on Pre Paid meters.

In order to improve the electricity revenue, the state Government initiated a pilot project for installation of 1000 nos. of pre paid meters in Dimapur. The Department selected an area near the main market consisting of 976 consumers fed by 4 nos. of Distribution Transformers. Some modifications in the distribution networks were under taken to isolate the pilot area. Under RAPDRP Part A ring fencing of the target area was carried out. The State Govt provided Rs. 214.29 Lakhs as under.

Table 7.3

Details Amount in Rs. Single Phase Smart Card Based Pre Paid meters 1000 nos @ 9500 each 95,00,000.00 Pilfer Proof Box 1000 nos @ Rs 1500 each 15,00,000.00 Installation of meters including, shifting of/new service wires @ Rs. 1650 ech 16,50,000.00 Magnetic Cards, printing, recharge booth - Lots 4,80,000.00 Consultancy, Software development and Commissioning - LS 51,63,000.00 AMC for 1 year - 10% 24,00,000.00 Seggregation and modification of 11KV and LT network for facilitating ring fencing - Lot 736000.00

Total 2,14,29,000.00

Implementation Period

The Work was awarded to Joint venture of M/s Universal Power Solution Kohima and Elmeasure in Bangalore in Nov 2013. Installation of meters started from 30th Nov 2013 and completed in Mar 2014.

Input Energy, Billed Energy and Collection Efficiency before pilot study and after pilot study. – Detail analysis is indicated below:-

Table-7.4

Before Installation of Pre-Paid Meter ACCOUNTING YEAR - 2013-14

Location DMC Guwahati Building

Old Daily Market

PK Travels Total

DT Capacity 250 KVA 500 KVA 500 KVA 100 KVA No .of Consumers

a). Domestic 227 311 153 20 b). Commercial 62 33 169 1 DT Input in Kwh 694980 994976 1091400 56366 2837722

Units Billed in Kwh 364140 433440 405720 26460 1229760 Revenue billed in Rs. 1638630 1950480 1825740 119070 5533920 Revenue Collected in Rs. 1248480 1593408 1719480 109620 4670988

Billing Efficiency 52.40% 43.56% 37.17% 46.94% 43.34%

Collection Efficiency 76.19% 81.69% 94.18% 92.06% 84.41%


Before Installation of Pre-Paid Meter ACCOUNTING YEAR - 2013-14


Old Daily Market

PK Travels Total

Units Realised in Kwh 277440 354091 382107 24360 1037997

AT&C Losses 60.08% 64.41% 64.99% 56.78% 63.42%

Table 7.5

After Installation of Pre-Paid Meter

ACCOUNTING YEAR - APRIL 2014-MAR 2015


Old Daily Market

PK Travels

Total

DT Capacity 250 KVA 500 KVA 500 KVA 100 KVA

No .of Consumers

a). Domestic 227 311 153 20 b). Commercial 62 33 169 1 DT Input in Kwh 594000 843200 940862 47768 2425830

Units Billed in Kwh 500341 684357 789208 45380 2019286

Revenue billed in Rs. 2419285 3202897 4631078 210685 10463945

Revenue Collected in Rs. 2419285 3202897 4631078 210685 10463945




AT&C Losses 15.77% 18.84% 16.12% 5.00% 16.76%

Note

Total Recharge Amount received/Credited- Rs. 10508630

Total Amount Debited for Energy consumption Rs. 10463945

Balance Recharge Amount Rs. 44685

ACCOUNTING YEAR - APRIL 2015 to 9th JAN 2016


Old Daily Market

PK Travels

Total


No .of Consumers

a). Domestic 227 311 153 20

b). Commercial 62 33 169 1

DT Input in Kwh 463867.377 757935 801924 21628 2045354

Units Billed in Kwh 377424 574300 621059 20469 1593252

Revenue billed in Rs. 1675608 2573740 2885593 89479 7224420

Revenue Collected in Rs. 1675608 2573740 2885593 89479 7224420




AT&C Losses 18.64% 24.23% 22.55% 5.36% 22.10%


ACCOUNTING YEAR - APRIL 2015 to 9th JAN 2016


Old Daily Market

PK Travels

Total


Note

Total Recharge Amount received/Credited- Rs. 7389000

Total Amount Debited for Energy consumption Rs. 7224420

Balance Recharge Amount Rs. 164580

Due to Non availability of fund to procure pre paid meters there are about 53 additional consumers with normal electro mech meters which accounts for nearly 8% of energy input and contributing towards AT&C losses.

Benefit Analysis

2014-15 Units loss from AT&C losses - 16.76%x DTR input 406544 Units Loss without prepaid - 63.42%*DTR Input 1538497 Units Saved/gained by prepaid meters 1131953 Additional Rev Generated - Avg billed tariff x unit saved A (Rs) 5865782

2015 - 9th Jan 2016 Units loss from AT&C losses - 22.10%x DTR input 452101.7 Units Loss without prepaid - 63.42%*DTR Input 1297193 Units Saved/gained by prepaid meters 845091.7 Additional Rev Generated - Avg billed tariff x unit saved B (Rs) 3831971 Total Benefit/Saving = A+B = Rs. 9697753


Saving & Benefit – The total saving in terms of additional revenue generation due to reduction of AT&C Losses is arrived at Rs. 96.97 Lakhs as indicated in the preceding benefit analysis table. After implementation of prepaid meters the following indirect benefits are factored. Customers are satisfied as they are able to judiciously monitor consumption thereby inculcating conservation of energy as is evident from the reduction of energy input at DT level after pre paid. Earlier Bill complaints and corrections which consumes most of time of the SDOs and JEs are now removed from the prepaid area since the management of the pilot project is done by the implementing Agency (UPS) under AMC. Dept is able to re deploy its manpower (meter readers) to other areas where it’s most needed. The officers and staff are able to devote quality time for power supply maintenance. Pre paid consumers are demanding 24x7 power supply. Sensing the positive impact made by pre paid meters and in view of scaling up the initiative for reduction of AT& C Losses , the Department proposed 28891 prepaid meters under IPDS for installation in the 3 most load/revenue intensive towns that of Dimapur, Kohima and Chumukedima under IPDS at a Cost of Rs. 33.59 Crores. Under IPDS the Dept submitted a DPR of Rs 230.33 Crores covering 12 towns. In addition to pre paid meters the DPR proposes other works also such as strengthening of distribution infrastructures, replacement of defective meters by electronic meters, roof top solar panel etc. However the MoP GOI has approved in principle Rs. 43.92 Crores only for 12 towns. With such meager allocation the prepaid meters which are a proven step for loss reduction cannot be taken up. Ministry of Power would consider the additional amount sought from the Govt. of Nagaland for prepaid metering in 3 towns as per the policies, rules and regulations of the scheme. However, Govt. of Nagaland may explore the other measure for funding the prepaid metering project such as loan from banks, REC/PFC.

Improving Consumer Convenience & Revamping Maintenance Philosophy O&M processes for consumer complaint management and network maintenance are manual in nature. Computerized system for recording complaint details and time taken for complaint resolution is under implementation in DOPN. There is no separate cell for handling consumer complaints in transmission division. However, a register is maintained to note the complaint in case information received over phone or in person. In distribution, every subdivision has a complaint center where consumers can lodge complaints either by self or over phone; which is known as fuse call center. Central complaint centre for taking consumer complaints is to be commissioned under RAPDRP, Part-A, at Dimapur. The complaints of the consumers shall be directly transferred to the concerned O&M team for resolution. The monitoring and reviewing of the complaints will be done at head Office Level. Consumer can also be able to register their complaints through SMS and Emails. Presently DOPN is engaged only in Break Down repair work of the various equipments. Deptt.is seriously considering to bring in certain level of preventive/predictive maintenance in the near future and setting up Transformer repairing unit and maintenance workshop in all district headquarters. For improving further and make the process more transparent state regulator can undertake Customer Satisfaction Survey through some independent agency. Performance Monitoring Mechanism

Though SERC has mandated Standard of Performance, however due to resource constraints DOPN is yet to comply. As far as consumer’s complaint is concerned, Deptt. Officials and staff always attend immediately unless it is a major breakdown of lines or transformers failures.


Revenue Collection target is fixed for every Division/Sub-Division every year. Close monitoring of Revenue/commercial performance is carried out at the Directorate and Circle level on fortnightly basis and monthly/bi-monthly with field officers. Since beginning of 2015, Monthly Revenue review cum Distribution Reform Committee meeting is being conducted every month under the Chairmanship of Chief Secretary of the state where Billing/Collection efficiency are the main focus. Also special focus is given on the High Value consumers.

Outsourcing of Meter reading and Bill delivery have been done in few areas of Kohima and Dimapur. In order to implement appropriate reform measures and meet the objective, baseline parameters needs to be verified and established, and hence it is proposed that a Third Party Audit should be carried out for establishing the baseline parameters for the KPI indicated below and thereafter following performance parameters needs to be monitored at the DISCOM Corporate level.

Table-7.6

Corporate Strategic Objectives KPI UOM Maximize Rate of Return PAT RsCrores

No of households to be electrified Nos in Lakhs CAPEX Rs. Crores

Sustain AT&C loss level & achieve further reduction

AT&C Losses % Collection Efficiency % Billing Efficiency %

Monitoring Distribution Cost Establishment Cost Rs. Crores R&M Cost Rs. Crores A&G Cost Rs. Crores Power Purchase Cost Rs./unit

Enhancing Customer Satisfaction CSI Overall Index Total Consumer Complaints/ '000 consumers Nos. New initiatives to enhance customer convenience Nos. Addition in regards to Payment Avenues Nos. PA Compliance Index Index

Operational Efficiency No. of customers served /employee Ratio System Reliability SAIDI Hrs

SAIFI nos. DTR Failure Rate % PADCI (Project Av. Duration Closure Index) Months No of Accidents (Fatal/ Non Fatal) Nos


ASSESMENT OF ADEQUACY OF DISTRIBUTION SYSTEM Table-7.7

Sl. No Description Units Existing As on

31.10.2015

Capacity addition up to FY 2018-19

Total

1 66/11 & 33/11 kV a New PSS Nos. 105 24 129 b Augmentation of PSS Nos. - 25 25 2 Total 66/11 & 33/11 kV PSS Capacity

including Augmentation MVA 264.10 326.9 591.00

3 11/0.415kV NEW Distribution Transformer Capacity

Nos. 3937 1197 5134

4 Total 11/0.415kV Distribution Transformer Capacity including Augmentation

MVA 354.97 95.23 450.20

From the above table it is evident that the transformation capacity at 66/11kV & 33/11kV levels is projected to grow from 264.10 MVA in FY2014-15 to 591.00 MVA in FY2018-19. The Projected peak demand of the state, including demand of large industrial consumers upto 33 kV level, has been Projected at 265.00 MW in FY 2018-19. The large industrial consumers comprise of only 11 kV Bulk consumers in case of Nagaland. The energy billed for HT (Industrial) for FY2014-5 is 1.39 MU. The demand met at 11 kV and below is 265 MW which corresponds to 294.44 MVA considering a power factor of 0.9. Against this peak requirement, the installed capacity at 66/11kV & 33/11kV levels in FY 2018-19 is projected at 591.00 MVA. This translates into an average loading of 49.82 % on 66/11kV &, 33/11kV transformers under peak demand conditions. From the aforesaid it can be concluded that the overall substation capacity planned for FY 2018-

19 would be adequate for meeting the projected demand. The transformation capacity at 11/0.415 kV level is projected to grow from 354.97 MVA in FY2014-15 to 450.20 MVA in FY 2018-19. Similarly the load of 11 kV consumers in FY2018-19 is about 0.40 MW. Correspondingly the demand met at 11 kV and below comes to 264.60 MW (265-0.4) which corresponds to 294.00 MVA considering a power factor of 0.9. Against this peak requirement, the installed capacity 11/0.415kV level in FY 2018-19 is projected at 450.20 MVA, This translates to an average loading of 65.30% on 11/0.415 kV transformers under peak demand conditions. From the aforesaid it can be concluded that Distribution transformation capacity planned at DT level for FY 2018-19 would be adequate for meeting the projected demand.


Fund Requirement The fund requirement for the GoI proposed scheme including other schemes

Table-7.8

(In RsCrores) Project

Cost FY 2015-16 FY 2016-17 FY 2017-18 Remarks

IPDS 230.33 0.00 131.18 99.15

Against a submitted DPR cost of Rs. 230.33 Crores for 12 towns, the MoP GOI/PFC accorded in principal approval of Rs. 43.92Crores only for 12 towns. To meet the objective of 24x7 in 12 towns additional fund allocation is required.

DDUGJY 342.21 0.00 157.90 184.31 Against a submitted DPR of Rs. 342.21 Crores for 11 districts, the MoP GoI/ REC has sanctioned Rs. 42.38 Crs. only.

Total: 572.54 0.0 289.08 283.46 Balance to be proposed to

GoI/State 486.24

ACTION POINT-FOR STATE GOVERNMENT 1. There are 141049 HH unelectrified in the

state (both rural and urban) as of 2015. In line with GOI policy of 24x7 Power for all, state Govt. is committed to take up 100% HH electrification. Under 12th plan RGGVY scheme, 39314 Nos. of Rural households have been sanctioned to be electrified. Under DDUGJY, 4381 & 56560 Nos. of rural households are planned to be electrified through UEV & system strengthening head of the DPR respectively. Balance 16228 Nos. of rural households shall be electrified departmentally since; infrastructure required for the same shall be constructed during execution of 12th plan RGGVY & DDUGJY DPRs. The 24566 nos. of urban household electrification shall take place departmentally while infrastructure will be laid down in IPDS scheme as per state’s requirement, subject to complete sanctioning of IPDS scheme as per DPR forwarded by the state.

2. To meet the agreed trajectory of AT&C loss, the deptt. is targeting reduction of ATC&

loss through implementation IT enabled system under on-going RAPDRP project and the proposed IPDS. One of the important intervention required is introduction of Prepaid meters in the 3 (three) major revenue generating towns of Kohima, Dimapur and Chumukedima.

3. To introduce modern technologies, to

monitor & quality supply Proposed for introduction of Autoreclosures for ease of maintenance and to restore power supply during transient line faults under IPDS. IT will also function to activate operation of sectionaliser and PFIs. During line faults, power outage takes places throughout the area fed by the feeder. On an average it takes 8 hrs to locate and restore the power. Therefore with Sectionaliser faulty sections will be isolated and power supply can be maintained in healthy sections and reduce restoration time. This will ensure stability of power supply and result into commercial gain by increase in billing. For quick location of faults and restoration of power supply. PFIs will function in tandem with Sectionalisers and Autoreclosures at SS.


Under RAPDRP modules such as GIS, Network analysis SAP driven ERP systems are incorporated in the scheme.

4. With negligible resources of its own, the state is wholly dependent on the central government funds for all development activities.

5. Electricity consumer in the state consists mainly of domestic (93%) and very small segment of commercial consumer exist (5%), who are paying much less than the cost of supply. Hence, the AT &C losses will increase further. If the objective of 24X7 PFA is to be met, there shall be provision to recover the cost supply without Govt. budgetary support to meet the ARR gap.

6. DOPN is Govt. department functioning

through budgetary support of the state Govt. fund resource under Plan and Non Plan which are sourced from GOI grant, Finance commission award and negotiated loan from financial institution 487 crores. Reducing of interest burden falls under State Govt .debt servicing.

7. There is an acute shortage of manpower both for maintenance and commercial activities. Shortage of Meter Readers - which is further compounded by not allowing enhancement of required manpower by Govt. due to resource constrains. Outsourcing of Meter reading and Bill delivery activities may be scaled up.

GOI Intervention

• To approve the whole amount of DPR submitted under IPDS with estimated cost of Rs. 230.33 crores (Rs.536.61 crores as per NAD) and DDUGJY with estimated cost of Rs. 487.00 crores (as per NAD) - DPRs for DDUGJY is under preparation to achieve reliable and secure 24x7 quality power to all and ensure reduction of AT&C loss as per agreed trajectory.

GoI may formulate mechanism for effective and timely implementation of the tariff policies, thereby lessening the gap between cost of supply and electricity tariff passed on to the consumers. This will reduce the financial burden on the state distribution utilities.


Renewable energy is increasingly becoming an important source of the energy mix- meeting the twin objectives of energy security and clean energy considerations. Nagaland has good potential for promotion and development of renewable and non-conventional energy projects, particularly Solar & Small Hydro Projects (SHP). State has already prepared liberal policies for promotion of renewable energy generation. Government of Nagaland is keen to tap renewable power potential of the state to meet the growing demand of power in an environmental friendly and sustainable manner. Cities of Kohima and Dimapur have already been declared as Solar Cities under the MNRE program of Solar/ Green Cities. The areas of studies are:

Renewable energy generation plans especially for Solar & Small Hydro based power projects

Renewable Energy Potential of Nagaland Renewable Energy policy framework in

Nagaland Government of Nagaland Initiatives &

RPO targets Action plan of the state Fund Requirements GoI/ State Govt Interventions

Grid Connected Renewable Energy The total grid connected Renewable Energy (RE) installed capacity (consisting of solar, SHP etc.) as on 31.03.15 is given in Table 8.1 below:

Table-8.1

Sl. No.

Ownership/ Sector

Mode wise Breakup (MW) Grand Total (MW) Solar Wind SHP Biomass

1 State 0.00 0.00 28.09 0.00 28.09 2 Private/ IPPs 0.00 0.00 0.00 0.00 0.00 3 Central 0.00 0.00 0.00 0.00 0.00 Total 0.00 0.00 28.09 0.00 28.09

The potential of generation of power through Renewable Energy Sources in Nagaland state is estimated to be about 7513 MW as indicated in Table 8.2 below:

Table-8.2

Sl. No. Type Estimated Potential in MW (as per MNRE) 1 Solar Power 7290.00 2 Biomass Power 10.00 3 Wind Power 16.00 4 Small Hydro Power (SHP) 197.00

5 Waste to energy 0.00

TOTAL 7513.00

Policy and notifications

The following policies are under preparation by New & Renewable Energy Department, Government of Nagaland (GoN):

a) Nagaland Renewable Energy Policy (Draft) 2011- Govt. of Nagaland.

b) Solar Power Policy (Draft) 2014 - Govt. of Nagaland.

c) Nagaland Electricity Regulatory

Commission (Terms and Conditions for Determination of Generation Tariff for Renewable Energy) Regulations, 2011

CHAPTER – 8 : RENEWABLE ENERGY STATUS AND PLAN


State Designated Agency

New & Renewable Energy Department, Nagaland is the State Nodal department for promotion and development of Renewable Energy projects. It is also the State department for Renewable Energy Certificates (REC) accreditation.

Renewable Purchase Obligation (RPO):

Every obligated entity, captive users, open access customers etc. shall purchase electricity from RE sources including solar. As per amendment in the tariff policy, revised solar RPO level to reach at least 8% of total consumption of energy, excluding hydro power, by March 2022 or as notified by the Central Govt. from time to time.

Table -8.3

Year FY 2015 -16 FY 2016 –17 FY 2017 - 18 FY 2018 - 19 Non Solar RPO (%) 7.75 7.75 7.75 7.75 Solar RPO (%) 0.50 1.50 2.75 4.00 Total RPO (%) 8.25 9.25 10.50 11.75

Capacity Addition Plan:

Year Wise Availability (Cumulative) through proposed capacity addition plan – through renewable (grid interactive) is as follows:

Table-8.4

Sl. No.

Particulars Year wise Existing & Likely Capacity to be added (MW)-Cumulative As on March 2015 FY 2015-16 FY 2016-17 FY 2017-18 FY 2018-19

a. Solar 0.00 0.00 20.00 60.00 60.00 b. Wind 0.00 0.00 0.00 0.00 0.00 c. SHP 28.09 30.19 30.64 32.74 40.34 d. Biomass 0.00 0.00 0.00 0.00 0.00

Total 28.09 30.19 50.64 92.74 100.34

Action Plan of the State for Grid Interactive NCE/RNES Plants:

The state has to ensure completion and addition of renewable generating capacities in the State of Nagaland as per the following roll out plan:

Table -8.5 Sl. No. Power For All (Roll

Out Plan) Year wise Addition (MW) Total (MW)

FY 2015-16 FY 2016-17 FY 2017-18 FY 2018-19 a. Solar** 0.00 20.00 40.00 0.00 60.00 b. Wind 0.00 0.00 0.00 0.00 0.00 c. Small Hydro Power 2.10 0.45 2.10 7.60 12.25 d. Biomass 0.00 0.00 0.00 0.00 0.00

Total 2.10 20.45 42.10 7.60 72.25

**:- Due to uncertainty in implementation, the energy from Solar Plants has not been factored while assessing the total energy availability in the State.


Total fund requirement (Year wise) for various projects is given here under: Table-8.6

Fund Requirement

Sl. No.

RES Projects

Total Cost of Project

Expenditure by State

Utility upto March 2015

Year wise Fund Requirement (Rs. Crores)

Remarks

FY 2015-16

FY 2016-17

FY 2017-18

FY 2018-19

a. Small Hydro Power

164.63 16.11 16.74 39.09 43.00 49.69 Funding: 102.37 Crores from MNRE and

balance from NEC and Ministry of DONER, GOI

b. Solar 600.00 0.00 200.00 400.00 0.00 0.00 To be implemented by SECI through VGF fund

( 2.5 Crores / MW) Total 764.63 16.11 216.74 439.09 43.00 49.69

Intervention by Govt. of Nagaland

a) GoN may submit their proposal to MNRE for VGF funding as per norms of the scheme.

b) Set up single window clearances mechanism to expedite clearances of NCE / RNES projects.

c) To provide solar energy generation based rebate in electricity bills for motivating consumers to install solar power plants.

d) Policies that are in Draft stage are needed to be finalized and put in place expeditiously.

e) The possibility of IPPs coming to the State

for development of Solar Projects does not look very encouraging.. In view of this, the

State may look into the possibility of developing Solar Projects of about 20 – 30 MW themselves with the support of MNRE, GOI.

Intervention by GOI

a) Viability Gap Funding (VGF) as applicable for various Solar Projects in the State.

b) Facilitate provision of fund for development of small hydro projects through MNRE, NEC and ministry of DONER.

Renewable Energy Initiatives of Govt. of Nagaland at Consumer Level:

For promoting generation through renewable at consumer level, various programs have been launched as indicated below in Table-8.7:

Table-8.7 Fund Requirement for Renewable Energy initiatives of Govt. Of Nagaland at Consumer Level

Sl. No.

Particulars Unit FY 2015-16

FY 2016-17

FY 2017-18

FY 2018-19

Total

A Grid Connected Solar Rooftop ( As per MNRE)

MW 1 6 6 8 21

Investment required Rs. Cr. 14 84 84 112 294 Subsidy from MNRE As Applicable

B Solar Off Grid System 1 Solar Power Plant KW 855 200 200 200 1455 Investment Required Rs. Cr. 22.00 5.10 5.10 5.10 37.30 Assistance from MNRE % As Applicable ---- Assistance from GoN % As Applicable ----

2 Solar Water Pump System No. 24.00 25.00 25.00 25.00 99.00 Investment Required Rs. Cr. 0.47 0.49 0.49 0.49 1.94 Assistance from MNRE % As Applicable ----- Assistance from GoN % As Applicable ----- Beneficiary % 50.00 50.00 50.00 50.00 50.00


Electrification of Un-electrified Hamlets

33 Nos. of Un-electrified hamlets in the state of Nagaland are to be electrified under remote village electrification programme (RVE) for which the DPR was submitted to MNRE by New & Renewable Energy (NRE) Nagaland vide their letter no. NRE/GEN-1/9/2010 dtd: 21.11.11. MNRE may look into the matter for implementation of the programme under RVE.

Intervention by Govt. of Nagaland

GoN may take up the electrification of 33 Nos. hamlets to MOP,GoI through RVE programme of MNRE. Intervention by GOI

Facilitate provision of fund for electrification of 33 nos. hamlets through MNRE, GoI


With increasing importance being given to low carbon growth these days, the cheapest and more affordable option to overcome the energy deficit is Demand Side Management (DSM) and implementation of energy efficiency measures in various sectors such as Agriculture, Domestic, Commercial, Street Lighting & Industries etc. The DSM has been traditionally seen as a means of reducing peak electricity demand. In fact, by reducing the overall load on an electricity network, DSM has various beneficial effects, including mitigating electrical system emergencies, reducing the number of blackouts and increasing system reliability. Possible benefits can also include reducing dependency on expensive imports of fuel, reducing energy cost, and reducing harmful emissions to the environment.

Finally, DSM has a major role to play in deferring high investments in generation, transmission and distribution networks. Thus DSM applied to electricity systems provides significant economic, reliability and environmental benefits. Opportunities for reducing energy demand are numerous in all sectors and many are low-cost, or even no cost, items that most enterprises or individuals could adopt in the short term, if good energy management is practiced.

Going by the experience of other states, the most common measures of DSM, as applicable to the State of Nagaland, is given in Table 9.1. The average normative approximate savings for each measure is also furnished in the Table.

Table-9.1

Sector DSM Technique Energy saving Potential as % of

total consumption

Investment/MU of savings (INR

Crores) Domestic Replacement of ICLs with LED bulbs 23% 0.8 Commercial Retrofitting of Energy efficient equipments 15% 1.5 Street lighting

Replacement of existing street light with LEDs

51% 2.0

Application of the above provides substantial energy savings per year. In Street lighting, the saving potential is maximum, because in this sector DSM can be planned and implemented by the authority. In other sectors, serious awareness campaign through stakeholders’ consultation is required to achieve and enhance the desired energy savings.

Enlisted below are some of the DSM measures and energy efficiency initiatives to be taken up by the state of Nagaland.

• Mandatory use of LED / CFL in Govt. buildings / Govt. aided institutions / Boards / Corporations.

• Promotion of Solar water heating system in domestic sector

• Solar Water Heating System to be made mandatory in industries where hot water is required for processing, hospitals and nursing homes, Govt. hospitals, hotels,

motels and banquet halls, jail barracks, canteens, housing complexes set up by Group Housing Societies/Housing Boards, all Govt. buildings, Residential Schools, Educational Colleges, Hostels, Technical/Educational Institutes, District Institute of Education and Training, Tourism Complexes etc.

• Use of star rated pumps to be mandated for PWW / PHED / Agriculture sector.

Government of Nagaland (GoN) Initiatives:

To encourage Energy Efficiency (EE) and DSM, GoN has taken up initiatives as indicated below:

a) Green Village initiative: Department of Electrical Inspectorate (DEI) had implemented replacement of ICL with CFL bulbs & Tube lights with LED light. This program is helpful in reducing the

CHAPTER – 9 : ENERGY EFFICIENCY


connected load by 1.80 MW and annual energy savings of 3.42 MU.

b) Replacement of Street Light

State is implementing new energy efficient street lighting schemes in various locations of Nagaland. DEI has taken up projects on energy efficient street lighting system based on LEDs and successfully completed installation of numbers of 80 watts & 90

watts LED street lights (508 No’s) in Nagaland.

The various measures taken up by State of Nagaland for implementation of DSM and Energy Efficiency measures till March 2015 are indicated in Table- 9.2.

Table- 9.2

DSM and Energy Efficiency Measures and its achievement till 31 Mar 2015

Sl. No.

PARTICULARS Qty. Energy saving per unit /year

(kWh)

Annual Energy

Savings (MU)

Reduction in connected load

(MW)

Remarks

1 Replacement of ICL (100watt) with 9 W LED bulbs

551 166.07 0.09 0.05 BEE

2 Replacement of I CL (60 watt) with 18 W CF L bulbs

721 76.65 0.05 0.03 BEE

3 Replacement of Tube Light (T-12) with LED Tube light(T-5)

2905 49.27 0.14 0.08 BEE

4 Replacement of street light (250 watt) with LED light (90 watt)

194 700.80 0.13 0.03 BEE

5 Replacement of I CL (60 watt) with 18 W CF L bulbs

29657

76.65 2.27 1.25 Green Village

6 Replacement of Tube Light (T-12) with LED Tube light(T-5)

18622

49.27 0.92 0.5 Green Village

7 Replacement of street light (250 watt) with LED light (80 watt)

314 744.6 0.23 0.05 Green Village

TOTAL 3.83 1.99

Policy and notification in Place Energy Conservation Building Code (ECBC) has been launched by Bureau of Energy Efficiency, MOP, GOI on 27th May, 2007 to be implemented on voluntary basis. The code is applicable to buildings/ building complexes that have a connected load/ contract demand of 100 kW/ 120 KVA and more or having conditioned area of 500 sq meters or more.

Agency responsible for DSM:

Department of Electrical Inspectorate (DEI) has been designated as State Designated Agency (SDA) to coordinate, enforce and implement the Energy Conversation Measures in the state in accordance with the provisions contained in the

Energy Conservation Act-2001 (Central Act 52 of 2002), in consultation with Bureau of Energy Efficiency (BEE), Ministry of Power, GoI.

Objectives and suggested Interventions

The doemstic sector accounted for about 64.20% (279 MUs) of the state’s total energy consumption (433 MUs) during 2014-15. Substantial saving potential (about 23% i.e about 64 MUs) exists in this sector through replacement programmes by energy efficient lighting and by promoting use of other energy efficient electrical appliances. In order to stimulate investments in energy efficient lighting projects, high quality LED lamps are proposed to be given to households at the cost of incandescent lamps (ICLs) to encourage them


to invest in energy efficiency under the Domestic Efficient Lighting Program (DELP).

The Domestic Efficient Lighting Programme (DELP) seeks to promote high quality LED lighting in the domestic sector by overcoming the high first cost barrier. DELP will enable sale of LED bulbs from designated places at a cost that is much less than the market price of Rs. 350-450 as replacements of Incandescent Lamps (ICLs). The programme is expected to

reduce installed load approximately by 35 MW and will lead to approximate annual energy consumption reduction of the state by more than 64 million KWh. The saved energy can be sold to better paying consumers like Industry and Commercial, which will provide additional revenue stream to the state utility.

ICLs are extremely energy inefficient form of lighting. In contrast, LEDs consume a fraction of energy used by ICLs to provide better light output. A single LED outlasts about 30 ICLs, and hence on life cycle cost effectiveness it fares better than ICL and CFL. However, the penetration of LEDs is very low because of their high first cost. To overcome this barrier, Energy

Efficiency Services Limited (EESL), has been implementing programmes in several states to provide high quality LEDs as replacements to ICLs and CFLs at a cost of Rs. 95-105 each to residential consumers.

EESL procures the LEDs bulbs and provides to consumers at an initial rate of Rs. 10 each (balance by DISCOM from energy savings or by consumer in installment) as against their market price of Rs. 350-450.

Approach / Strategy

All the above interventions involve replacement of inefficient equipment / appliances with energy efficient ones for the domestic, commercial buildings and Street Lighting Sectors. These can be undertaken by the State Government at no upfront cost by using the Energy Service Company (ESCO) model. The model is based on the concept of promoting Performance Contract mode where the company invests in any project by entering into a contract agreement with the facility owner which is recovered through the savings accrued due to reduced electricity bills.

Future Plans of State of Nagaland:

Future Planning of State of Nagaland for DSM and implementation of Energy Efficiency measures are given in the Table-9.3 below.

DELP KEY FEATURES - LED at cost of Rs. 95-105 as against a market

price of Rs 350-450 - Consumer take LED bulb at Rs. 10/-, Balance

paid by DISCOM from energy savings or by consumer in 8-12 months installment.

- 3 years free replacement warrantee - No impact on tariff - Total upfront investments by EESL - Benefits sharing approach


Table 9.3

Sl. No.

Particulars FY 2015-16 FY 2016-17 FY 2017-18 FY 2018-19

Replacement of ICL

(60 watt) with 9 W

LED bulbs

Replacement of street light (250 watt) with

LED light (80 watt)

Replacement of ICL (60

watt ) with 9 W LED bulbs

Replacement of street

light (250 watt) with LED light (80

watt)

Replacement of ICL (60 watt ) with 9 W

LED bulbs

Replacement of street

light (250 watt) with LED light (80 watt)

Replacement of ICL

(60 watt)

with 9 W LED bulbs

Replacement of street light (250 watt)

with LED light (80

watt)

1 Quantity 48620 2000 48620 2000 48620 2000 48620 2000

2 Energy saving per unit /year (kWh)

93.07 744.60 93.07 744.60 93.07 744.60 93.07 744.60

3 Annual Energy Savings (MU)

4.52 1.48 4.52 1.48 4.52 1.48 4.52 1.48

4 Reduction in connected load (MW)

2.48 0.34 2.48 0.34 2.48 0.34 2.48 0.34

Note: State Government allocation has been fixed as Rs. 0.5 Crores per year. Balance fund has to be made available by GoI.

Actions Point

The sector-wise Central Government and State Government actions envisaged to facilitate implementation of energy efficiency measures as mentioned above are detailed below:

Central Government

• BEE may consider formulation of specification for LED bulbs and introducing star label scheme for LED bulbs.

• Energy Efficiency Services Limited (EESL) to take up project design and project development.

• To expedite provision of fund to the State Government for implementation of DSM and Energy Efficiency Measures.

State Government

• Ensure formulation of a detailed time line in consultation with concerned departments for implementation of DSM and Energy Efficiency Measures in the State.

• Ensure establishment of a payment security mechanism so that the company making investments under the ESCO mode recovers the same through the savings accrued due to reduced electricity bills.

Central Government

• BEE may provide technical support for effective enforcement of ECBC and

promotion of ESCO based retrofitting works in Government buildings. BEE can provide support for capacity building of state department through establishment of ECBC cells for compliance of ECBC and retrofitting in Government buildings.

• Energy Efficiency Services Limited (EESL) to take up project design and project development for retrofitting in commercial buildings.

State Government

• Government of Nagaland has to adopt ECBC Directives for new commercial building design and mandated energy audit of existing commercial building once in a three-year period. Effective enforcement of ECBC compliance and mandating retrofitting in energy-audited buildings may result in reduction of electrical consumption from commercial sector. Government of Nagaland may consider mandatory retrofitting in Government buildings with an objective of reduction of electricity bills, which state government is paying against electricity bill of these buildings. This would also demonstrate impact of ESCO based retrofitting projects to private building owners to adopt the same.

• As per the Planning Commission’s projection; residential building are becoming one of the larger consumers of


electricity in the country by 2030. BEE is introducing design guidelines for energy efficient multi storey residential apartments including in the composite and hot & dry climatic zone. State Government may mandate compliance of these guidelines through institutional framework in the state.

• For residential buildings, the state could adopt the star labeling scheme for multi-

storey residential apartment buildings, being prepared by BEE.

• In addition to the above, Nagaland Electricity Regulatory Commission (NERC) may be requested to issue directives for creation of DSM funds by Utilities of the State so that DSM activities can get extra emphasis. Such funds can be utilized for meeting incremental cost of efficiency improvement.


Financial Viability

Based on the road map discussed in the previous chapters, various scenarios have been prepared to visualize the profitability from operating the business as per the roadmap laid down and sensitivity thereof with changes in important input parameters like tariff and AT&C losses. However, the analysis has been restricted up to FY 2018-19 being the analysis framework for 24x7 PFA initiatives.

The following scenarios have been detailed in subsequent sections:

a) At targeted growth rate and other parameters as per “24x7 Power for All” Road Map (Base case).

b) Same as (a) and tariff hikes for viability, if required.

c) Non-Adherence to AT & C Loss Reduction Trajectory and subsequent dependence on higher tariff hike for viability.

d) At targeted growth and loss reductions as per roadmap and all fundings including those under GOI schemes as per Debt equity ratio of 70:30.

Common Assumptions

1. Average cost of power purchase has been considered as Rs. 4.04 per unit. The details are given as hereunder:

Table-10.1

FY 2015-16

Sl. No.

Description Unit Total

A Units Purchased

1. Total power purchased

MU 627.11

2. Less PGCIL Losses MU included

3. Net power purchased(At state periphery)-A

MU 627.11

B Power purchase cost

1 -Total power purchase cost

Rs Cr. 224.81

2 NERLDC charges Rs Cr. 1.10 3 -PGCIL charges Rs Cr. 27.33

Sl. No.

Description Unit Total

4 Total cost of purchase-B

Rs Cr. 253.24

Average purchase cost(At state periphery) (B/A)

Rs/ kWh

4.04

Source: Tariff Order for NERC for FY 2015-16

The details of power purchase cost from various generating stations for Nagaland is given in Annexure-XII.

2. No change in power purchase cost, as any change in the power purchase cost will be taken care by the Fuel and Power Purchase Cost Adjustment mechanism.

3. Escalation towards O&M cost (excl employees cost) and administrative and General expenses has been considered @ 6% p.a. in line with average changes in WPI;

Table-10.2

Month/ Year WPI Indices

CPI Indices

Average 2012-13 168 215 Average 2013-14 178 236

Increase 5.95% 9.8% Say 6.0% 10%

Source: eaindustry.gov.in

4. Escalation towards Employee Cost has been considered @ 10% p.a. based on CPI Indices.

5. Purchase Demand considered as forecasted in previous chapters.

6. Grant, Loan and Equity ratio has been considered as 85%:10%:5% for DDUGJY/IPDS schemes as Nagaland comes under Special Category States. All other investments have been considered for funding as per Debt equity ratio 70:30. Additional grant of 5% of IPDS & DDUGJY has been taken from 3rd year onwards. Funding in NERPSIP Plan is treated as 95% grant and 5% loan as per its guidelines.

CHAPTER – 10 : FINANCIAL VIABILITY


7. Ongoing schemes like RGGVY is considered as per their respective guidelines and all other investments have been considered for funding as per Debt equity ratio 70:30.

8. Project completion period has been considered as 2 years and its Interest During Construction (IDC) has been capitalised.

9. Interest on future long term loan and Working Capital loan has been calculated @ 12% p.a. as per existing loan profile.

10. The existing average billing rate was Rs 4.84/kWh in FY 2015-16 based on NERC tariff order for FY 2015-16. However, from FY 2015-16 to FY 2018-19, the average billing rate has been considered based on weighted average ABR, as shown hereunder:

Table-10.3

Year Rs./kWh FY 2015-16 4.53 FY 2016-17 4.50 FY 2017-18 4.50 FY 2018-19 4.51

The details of weighted average billing rate is given in Annexure-XIII.

11. The interstate sale of surplus energy has

been considered at the rate of 4.04 Rs/kWh as per the average power purchase cost based on tariff order for FY 2015-16.

12. Depreciation has been computed @ average 5.02% for existing assets and 5.28% for new incoming assets.

Scenario A: Targeted Growth Rate as per

24x7 Road Map (Base Case) Assumptions

No tariff hike and change in power purchase cost.

AT&C losses as per targeted MoP trajectory.

.


Table-10.4

Financial Position of the Utilities (Scenario A)


The projected scenario exhibits the continuation of loss making situation in the forthcoming period and tariff hikes would be required if turnaround is to be achieved.

Scenario B: Targeted Growth Rate as per 24x7 Road Map and Turnaround with Tariff Hikes.

Assumptions All other assumptions as per Base-

case(Scenario-A)

Turnaround considering tariff hike.

Table-10.5

Financial Position of the Utilities (Scenario B)


The scenario exhibits the extent of tariff hikes required to make turnaround of situation as shown under scenario –A. The tariff hikes to the tune of 17% in FY 2016-17, 16% in FY 2017-18 and 14% in FY 2018-19 would be able to make turnaround by FY 2018-19.

Scenario C: Non-Adherence to Performance Parameters (Loss Reduction Trajectory) and subsequent dependence on Higher Tariff Hike.

Assumptions AT&C losses higher by 1% than the targeted

trajectory. Power purchase cost constant for all the

years.

Table-10.6

Financial Position of the Utility (Scenario C)


The scenario exhibits that non adherence to AT & C Loss reduction trajectory would compound the losses further and higher tariff hikes to the tune of 17% in FY 2016-17, 16% in FY 2017-18 and 15% in FY 2018-19 may be required to observe a turn around by FY 2018-19.

Scenario D: Targeted Growth Rate as per 24x7 Road Map and Considering all funding including GoI Schemes in the Debt Equity Ratio of 70:30.

Assumptions At targeted growth rates and loss reduction

as per road map. Considering all funding including GoI

Schemes in the Debt Equity Ratio of 70:30.

Table-10.7

Financial Position of the Utility (Scenario D)


This scenario exhibits that absence of grant funds would make considerable dent on overall profitability and tariff hikes to the tune of 18% in FY 2016-17, 18% in FY 2017-18 and 17% in FY 2018-19 would have to be resorted to in order to see turnaround by FY 2018-19.

UDAY SCHEME

Financial implication of UDAY Scheme has not been considered in view of MoP Office Memorandum No.06/02/2015-NEF/FRP(Pt.) dated 13th January 2016. However, Power Department of Nagaland may sign MoU with MoP on efficiency parameters stated in UDAY Scheme.


Communication

Successful implementation of 24X7 Power Supply Scheme requires clear communication among all the stakeholders across the value chain, including the consumers. In order to avoid potential roadblocks in implementation due to poor communication and flow of information, the following table lists the primary responsibility of each stakeholder and the corresponding method in which it will be carried out.

A centralized corporate communication team can be formed at headquarters of the DISCOM for looking at activities of overall communication strategy.

The financial situation in Nagaland makes it imperative to raise tariffs while other initiatives including 24X7 supply are implemented. Such tariff increases would inevitably impact consumers and meet with resistance. To address this, the utilities would clearly communicate their plans on implementing the reliable 24X7 supply scheme along with the other reliability and efficiency improvement measures that they are implementing. A high level of involvement of the Government of Nagaland will also be required.

Table-11 .1 Proposed communication responsibilities

Communication Objective Responsibility Frequency “ Power for all” - Roll Out Plan Secretary, Power Quarterly Power Supply Position CE (D&R) Daily Energy Savings & Conservation CEI , Office of The State Electrical

Inspectorate, Nagaland State Designated Agency on Energy Conservation

Monthly

Planned Outages & Disruption CE (D&R) Daily Real time feeder-wise Information CE (D&R) Daily Status update on Deliverables Secretary, Power Quarterly Renewable Power Director, State New &Renewable Energy

Department Quarterly

Generation- Projects, PLF & Fuel CE (T&G) Monthly Transmission Projects – Physical Progress and Achievements

CE (T&G) Monthly

Distribution – Progress ,Achievements, Losses, Consumer Initiatives etc.

CE (D&R) Monthly

Information Technology Initiatives

The need to adopt IT in every sphere of utility operation is pervasive. Power is a complex product that must be consumed on a real time basis. The overall value involved in the process is very high. Even more importantly it touches all citizens. Yet, the information systems that drive the operations of the sector are generally very basic and information transparency and consistency is poor. While sporadic efforts have been made in the past to improve this, quantum changes are required to increase IT adoption in all spheres of power sector operation.

In Nagaland, IT adoption on a massive scale will required to be pursued in the following areas:

At the corporate level, the operations need to be integrated through implementation of Enterprise Resource Planning Systems (ERP). This would cover critical aspects like Finance and Accounts, Asset Management, Inventory Management, Human Resource Management, Project Management, Personal information System (PIS). ERP will help in timely capitalization of asset, deriving better business value of investment etc.

CHAPTER – 11 : OTHER INITIATIVES


At the commercial operations level there is a need to comprehensively implement Customer Management Systems (CMS) for undertaking customer related processes including billing and collections, customer complaint management, new connection provision etc.

Centralized Information & Monitoring System for operational, enforcement & litigation, vigilance activities and analysis.

Power management would require the institution of technically capable controlling facilities equipped with tools like SCADA and Distribution Management Systems (DMS) that allow for adequate visualization of the networks and response capabilities. Technologies for sub-station automation, GIS, SCADA, DMS, OMS, etc., shall be adopted. For the urban areas SCADA is quite useful for improving reliability and reduction of network downtime.

Regional Distribution Control Centres (RDCC) within the State are proposed to be established. These will initially cater to the principal load centres, but would thereafter be expanded to all load centres of the state. This will be a key initiative, not only for effectively managing 24X7 supply, but also thereafter for other functions like forecasting.

Renewable Energy Management centres shall be established and equipped with adequate capabilities through financing availed from KfW and ADB.

Power procurement optimization tools will be implemented to reduce the power procurement costs and improve supply reliability. This shall be achieved through the institution of technically robust forecasting, scheduling and dispatch (Unit Commitment) and settlement tools. The tools shall be used to ensure that the control room operators have the ability to take real time decisions to ensure cost reduction.

Project monitoring tools shall be incorporated in the PMU to ensure that progress on the investments in the state

are monitored rigorously and bottlenecks identified.

Standards of service specified under Section 57 of the EA 2003 shall be monitored. The utilities shall use IT tools to gather the information with regards to service standards with minimal manual intervention to ensure transparency and credibility.

The above need to be implemented urgently, and also need to be integrated with each other to ensure that the systems are inter-operable (i.e., they can talk to each other). For this the utilities shall evolve a detailed IT plan to implement the above in a well-coordinated manner.

Institutional Arrangement

A strong monitoring framework is essential to ensure the success of the “Power for all” scheme. The following structure is being proposed to undertake regular monitoring of the progress of all initiatives being under-taken in this scheme.

Government of India (GOI) Level Committee: It is proposed that this committee will review the overall progress of the scheme on a quarterly basis and provide necessary support to ensure a coordinated response from the Central Govt. - where necessary. The committee may be constituted with the following members – PFC, REC, CEA, SECI, EESL, Ministry of Power Ministry of Coal, and MNRE.

State Government Level Committee: It is proposed that a State level committee headed by the Chief Secretary will be formed to review the progress of the scheme on a quarterly basis. This committee will monitor the progress of the works undertaken as part of the scheme and issue directions to enable faster execution. This committee will be constituted with the following Principal Secretaries/ Secretaries of the Power, Finance, Urban Development, Agriculture and other relevant departments along with the CMD/Chairman/MD/CE of state utilities.


Department Level Committee: It is proposed that the Department level committee headed by theACS power/Secretary Power will be formed and shall undertake steps required to ensure the projects are progressing as per the action plan. This committee will undertake progress reviews on a monthly basis. The committee will be constituted with the following members –ACS Power /Secretary Power and MD/CEs of state power utilities.

District Level Committee – It is proposed to constitute a district level committee headed by the Deputy Commissioner to take action that is necessary to ensure the projects are completed in a timely manner and address any issues pertaining to land or other relevant approvals. The committee will be constituted with the following members – Deputy Commissioner and Superintendent Engineer of state utilities.

Project Monitoring Unit (PMU) – A project monitoring unit shall be set up for monitoring the progress of the works being undertaken under this scheme. The PMU will operate under the Secretary, Energy and shall be operated by an external independent agency. The PMU shall be responsible for undertaking coordination, preparing the action plans and monitoring progress of all works under the “Power for all” scheme. The PMU would also help facilitate in tracking the action steps and providing feedback to the various committee that are proposed to be set up under the scheme. Government of India shall provide grants for the PMU operations.

The committees that are being proposed above are required to be set up at the earliest to kick start the whole scheme. It is important that the committees keep meeting on a regular basis as per the frequency/ timelines mentioned above – to ensure that the objectives set out under the “Power for all” scheme are achieved.

Capacity Building

With the increase of IT in the Generation, Transmission & Distribution system and to meet the expectations of 24 X 7 power supply for the consumers in the state, it is important to focus on capacity building of the employees for enhancement of technical know-how for latest technological developments and to increase the consumer satisfaction. The capacity building may also include consumer grievance system, awareness regarding importance of working with safety, outage management system, demand side management etc. It is also imperative to state that for serving the consumers in a different way change of mindset of the employees would be required. It is critical that Change Management initiatives are rolled out and institutionalized throughout the Department for achieving better results. The details of the present employee in the Department of Power Nagaland (DOPN) is as under:

Employee base

As on 01.04.2015 Name

of Dept.

Sanctioned strength

Working position

Vacancy position

Engaged through

outsource

Net vacancy

DOPN 2778 2626 152 0 152

% vacancy

5.47 5.47

In view of the importance of the training on new technologies, there is a requirement for development and implementation of Human Resource training programme so as to realize the dream of 24 X 7 power supply system in the state in its true sense.

There is already a provision for Demand Side Management (DMS) trainings under various programmes of Bureau of energy Efficiency (BEE) and the same should be implemented to achieve the goal of 24 X 7 power for goal. The organization does not have a system for mapping the skill levels and there is no setup for capability development. The employees at various levels & functions at Department of Power have built their capability/skills largely through on-the-job experience. However, some training programs are being conducted at various levels.


Following training programmes were conducted by DOPN in the previous financial years for up gradation of knowledge base of their Employees and will also be conducted in the coming years:

Table-11.2

Sl. No. Name of institute Training module

1. Central Board of Irrigation & Power Circuit Breakers and Protection 2. ISGF Cyber Security for Power Systems 3. PHD Chamber of Commerce & Industry North Eastern Region Infrastructure Conclave 4. Central Board of Irrigation & Power Cable Fault Location, Testing and Diagnostics and Fault

Location on overhead Transmission Lines 5. Central Institute for Rural Electrification Power Factor Improvement and Reactive Power

Management 6. HMG Electric Power System - Condition Monitoring &

Maintenance 7. REC National Electricity Fund (NEF) 8. NTPC Limited Customer Conclave for North Eastern Region 9. CIRE Design and Operation & Maintenance of Hydro Power

Generating Plants 10. IIT, Gujarat Seismic Design of Re-enforced Concrete Buildings 11. Engineering Staff College of India Network Planning & Analysis Employing GIS 12. CIRE Pilferage of Electricity- Issues, Challenges and Remedial

Measures 13. CIRE Latest Trends in Metering and Billing Technology 14. Engineering Staff College of India Modern Practices in Design and Construction of EHV S/S 15. CIRE East/ North Eastern Regional Workshop on Franchisee

Arrangement 16. Central Electricity Authority Implementation of National Training Policy (NTP) 17. NTPC Limited Distribution Loss Reduction & IT Intervention 18. NTPC Limited Demonstration of Energy Audit Techniques 19. NTPC Limited Information Flow System for Billing & Realization 20. NTPC Limited Switch gear Maintenance Practices 21. NTPC Limited Demonstration of Predictive Maintenance Technique 22. NTPC Limited Breakdown Analysis & Remedies

The Establishment employees undergo specific training programs on service rules & office management. The same are conducted by the state’s Administrative Training Institute (ATI) on periodic basis. Similarly, the Engineering staff undergo trainings conducted by various institutes as elaborated above. In addition,

some engineers, in the past, have also undergone trainings abroad on Energy Efficiency, Energy Conservation, Detailed Project Report (DPR) preparation etc. Following courses are proposed to be conducted in FY 2015-16.

Table-11.3

Sl. No. Name of the Course 1. HR for Line Managers in Power Sector 2. Best Practices in Operation and Maintenance of EHT Sub-Stations and Lines 3. Open Access, Power Trading and ABT 4. Earthing, Lighting and Electromagnetic Interference 5. Energy Infrastructure in North East 6. Crisis & Disaster Management in Power Sector and Associated Environment


Deliverables

Power for All – Roll Out Plan Units FY 2015-16 FY 2016-17 FY 2017-18 FY 2018-19 Total (A) GENERATION

State Sector MW 2.10 0.45 2.10 7.60 12.25 Central Sector MW 45 20 20 0.00 85.00 IPP Projects MW 0 20 40 0 60 Total

47.1 40.45 62.1 7.6 157.25

(B) TRANSMISSION Inter State

Substation (Augmentation) 220/132 KV Nos/MVA 0 0 0 0 0

Intra State Substation (New) 220/132 KV Substation Nos/MVA - 1/100 - - 1/100

132/33 KV Substation Nos/MVA 1/24 4/55 - 7/345 12/424 132/11 KV Substation Nos/MVA - - - 1/12.5 1/12.5 66/11 KV Substation Nos/MVA 1/20 - - - 1/20 Lines (New) 220 kV Lines Ckt Km - - 69 92 161 132 kV Lines Ckt Km 84.6 20.77 48.71 275.4 429.48 66 kV Lines Ckt Km 55 - - - 55

(C) DISTRIBUTION New 33/11 kV PSS Nos 0 5 17 0 22

MVA 0 35.5 115.7 0 151.20 Augmentation of 33/11 kV PSS Nos 1 12 12 0 25

MVA 2.5 74.1 59.1 0 135.70 R & M work in existing 33/11 or 66/11 kV Substations

Nos. 0 05 02 0 7

New 33 kV Bay No. 0 5 3 0 8 New 11 kV Bay No. 2 0 0 2 New 33 kV Feeder Ckt Km 8 160 118.5 0 286.5 Re conductoring of 33 kV Feeder Ckt Km 10 10 0 20 New 11 kV Feeder Ckt Km 5 87.7 72 0 159.7 Re conductoring of 11 kV Feeder Ckt Km 09 0 0 9

CHAPTER – 12 : YEAR WISE ROLL OUT PLAN


Deliverables

Power for All – Roll Out Plan Units FY 2015-16 FY 2016-17 FY 2017-18 FY 2018-19 Total 33 kV Spur line for DT Ckt Km 4 4 0 0 8 11 kV Spur line for DT Ckt Km 160.88 588.25 388.4 0 1137.53 DTR (New) 16 kVA No. 5 0 0 0 5 25 kVA No. 114 336 233 0 683 63 kVA No. 52 110 93 0 255 100 kVA No. 2 51 07 0 60 250 kVA No. 0 49 64 0 113 DTR (Augmentation) 25 kVA 0 03 0 0 3 63 kVA 0 08 0 0 8 100 kVA No. 0 05 0 0 5 250 kVA No. 0 17 08 0 25 500 kVA No. 0 19 22 0 41 R & M of DTR No. 0 250 316 0 566 New LT Line Ckt Km 125.33 595.85 472.65 0 1193.83 Service connection to BPL Consumers No. 16849 51158 32610 0 100617 SS & Feeder Metering No. 0 217 58 0 275 DTR Metering No. 0 1276 946 0 2222 Consumer Prepaid Meter No. 0 16000 12891 0 28891 Consumer 1Ph LT Electronic meters No. 0 91800 99553 0 1017553 Relocation of inaccessible meters No. 0 8650 7150 0 15800 Roof Top Solar Panel No. 0 07 13 0 20 OPGW/ADSS Km 0 146.5 87 0 233.5 AT&C Loss % 54.21 46.71 39.21 31.71 - House Hold Electrification Target UN-ELECTRIFIED HH No. 0 61350 58905 20794 141049 NEWLY ELECTRIFIED HH No. 10093 10557 11046 11561 43257 UE VILLAGE ELECTRIFICATION PROGRAMME

No. 0 42 40 0 82

(D) RENEWABLE ENERGY (ALREADY INCLUDED IN GENERATION UNDER ITEM (A) ABOVE) Solar PV MW 0 20 40 0 60 SHP MW 2.10 0.45 3.60 7.50 13.65

Total Renewable MW 2.10 20.45 43.60 7.50 73.65


(In Rs. Crores)

Sector FY 2015-16

FY 2016-17

FY 2017-18

FY 2018-19

Total Remarks

Generation State Owned

Projects

Future Hydro Projects under consideration (Zungki 24MW, Lower Tizu, 36 MW, TizuVally 15MW)

65.00 230.00 300.00 133.00 728.00

Proposed for 100% funding by GoI (to be commissioned after FY2018-19)

Hydro Electric Projects under R & M (Tsutha 0.75MW, Duilimroi 0.54MW, Dzuza 1.5MW and Telangsao 0.6 MW)

8.00 10.00 10.00 2.38 30.38

Proposed for 100% funding by GoI (to be commissioned after FY2018-19)

SHP Projects 16.74 39.09 43.00 49.69 148.52

Funding : 102.37 Crs. from MNRE and balance from NEC and Ministry of DONER, GoI

Total Generation

89.74 279.09 353.00 185.07 906.9

Transmission Intra State New GSS 61.47 136.82 - 61.41 259.70 Funding related to NERPSIP & PGCIL Projects has not

been taken into consideration since details & Phasing of the expenditure

are not available.

Augmentation (Bay addition on existing sub-stations)

- - - 14.44 14.44

Transmission line 50.03 28.50 5.94 30.34 114.81 Inter State - - - - -

Total Transmission 111.5 165.32 5.94 106.19 388.95 Distribution IPDS (Future Scheme) - 131.18 99.15 - 230.33 DDUGJY (Future Scheme)

- 157.90 184.31 - 342.21 Sanctioned

Schemes

RGGVY XII Plan 36.55 50.91 - - 87.46 DDUGJY UE Plan 12.49 27.78 - - 40.27 NERPSIP DMS Plan - 56.47 50.28 - 106.75

Total Distribution 49.04 424.24 333.74 - 807.02 GRAND TOTAL 250.28 868.65 692.68 291.26 2102.87

CHAPTER – 13 : SECTOR WISE INVESTMENT PLAN & FUND REQUIREMENT


ANNEXURE-I GoN Data

Category-wise Growth in consumers

Consumers Year-wise figures from FY 2009-10 to FY 2014-15

FY 2009-10

FY 2010-11

FY 2011-12

FY 2012-13

FY 2013-14

FY 2014-15

(i) Domestic 164515 170679 172846 180000 224480 237946 (ii) Commercial 17273 17050 17612 18800 11383 12064 (iii) Industrial 2095 2040 2050 2400 1873 1986 (iv) Bulk 556 585 600 700 577 610 (v) Traction 0 0 0 0 0 0 (vi) Agriculture 2 2 2 2 0 0 (vii) Others

(Including Interstate)

608 809 631 631 2313 2451

Total 185049 191165 193741 202533 240626 255057

*Note: 1. Figures for FY 2009-10 to FY 2012-13 are as per NERC Tariff order 2015-16. 2. Figures for FY 2013-14 to FY 2014-15 are as per State provided Data.


ANNEXURE-II

Census 2011 Data of Households in Nagaland

Description Rural Urban Total

No. (%) No. (%) No. (%) No. of Households in Nagaland 284911 71.23 115054 28.77 399965 100 No. of Electrified Households 214319 65.66 112086 34.34 326405 81.61 Balance Un-electrified Households

70592 95.97 2968 4.03 73560 18.39

(Source: Census of India-2011)


ANNEXURE-III

Detailed Calculation of energy Demand in the State of Nagaland up to FY 2018-19

Sl. No.

Particulars→ ↓

Calculation steps Years

FY 2015-16

FY 2016-17

FY 2017-18

FY 2018-19

A DEMAND PROJECTIONS FOR ELECTRIFIED HOUSEHOLDS

1 Consumption of Rural Electrified Households

2 Consumption (units per day per household) Units 1.96 2.20 2.46 2.76

3 Annual Energy Requirement for existing electrified Rural Household MU 126.38 141.86 158.62 177.96

4 Consumption of Urban Electrified Households

5 Consumption (units per day per household)

Units 5.88 6.64 7.50 8.48

6 Annual Energy Requirement for existing urban electrified Household

MU 254.35 287.22 324.42 366.82

7 Total Annual Energy Requirement for existing electrified households(A3+A6)

MU 380.73 429.08 483.04 544.78

B ADDITIONAL ENERGY REQUIREMENTS FOR ELECTRIFIED DOMESTIC CONSUMERS

1

Additional Energy Required for Electrified Households (Annual projection (-) current Energy available MUs)

MU 42.88 91.23 145.19 206.93

C ELECTRIFICATION OF UNELECTRIFIED HOUSEHOLDS ( per year) URBAN

1 Unelectrified Household as on 31.03.2015

24566 Nos.

2 Electrification of unelectrified Household Nos. 0 10000 10000 4566

3 Cumulative Annual Energy Requirement for Electrification of unelectrified urban Household

MU 0 24.24 54.75 76.04

RURAL

4 Unelectrified Households 116483 Nos.

5 Targeted Electrification of unelectrified

6 Electrification of unelectrified Household

Nos. 0 51350 48905 16228

7 Cumulative Annual Energy Requirement for Electrification of unelectrified rural Household

MU 0 41.23 90.02 117.35

8 Total households electrified out of unelectrified

Nos. 0 61350 58905 20794

9 Annual Energy Requirement for Electrification of unelectrified Household

MU 0.00 65.47 144.77 193.39


Sl. No.

Particulars→ ↓

Calculation steps Years

FY 2015-16

FY 2016-17

FY 2017-18

FY 2018-19

D ELECTRIFICATION OF NEWLY CONSTRUCTED HOUSEHOLDS ( per year)

URBAN

1 Total Household - Urban (nos.) 2014

Yearly Increase in Urban H/H Nos 8012 8461 8935 9435

2 Yearly cumulative Increase in Urban H/H as per GoN

Nos. 8012 16473 25408 34843

3 Cumulative Annual Energy Requirement (MUs) for newly constructed Household - Urban

MU 17.20 39.92 69.55 107.85

RURAL

4 Total Household Rural 2014

5 Yearly Increase in Rural H/H as per GOH

Nos. 2081 2096 2111 2126

6 Yearly cumulative Increase in Rural H/H as per GOH

Nos. 2081 4177 6288 8414

7 Annual Energy Requirement for newly constructed Household MU 1.49 3.35 5.65 8.48

9 Total newly constructed households Nos. 10093 10557 11046 11561

10 Cumulative Annual Energy Requirement for newly constructed Household

MU 18.69 43.27 75.20 116.33

E ANNUAL ENERGY REQUIREMENTS

1 Total Additional Annual Energy Requirement - Domestic Consumer MU 61.57 185.02 333.81 516.65

2 Current Energy Available - Total MU 400.77 400.77 400.77 400.77

3 Current Energy Available - Domestic MU 337.85 337.85 337.85 337.85

4 Total Domestic Annual Energy Requirement (Current + Projection) MU 399.42 537.82 703.01 854.50

5 Current Energy Available - Other than Domestic MU 62.92 62.92 62.92 62.92

6 Total Annual Energy Requirement - Other than Domestic Consumers (with 25.79% growth P.A.)

MU 79.15 99.56 125.24 157.54

7 Additional Energy Required for other than domestic Categories of Consumers (year wise)

MU 16.23 20.41 25.68 32.30

8 Additional Energy Required for other than domestic (Cumulative) MU 16.23 36.64 62.32 94.62

9 Total Energy Requirements (all) Nos. 478.57 637.38 828.25 1012.04


Annexure- IV Breakup & Details of Capacities existing and Likely to be added year wise

Sl. No Power Sources/

Generating Stations Type

(Thermal/ Hydro/

RES etc.)

Location of the Plant

As on March 2015

Capacity Available as Planned Remarks

FY 2015-

16

FY 2016-

17

FY 2017-

18

FY 2018-

19

(MW) (MW) (MW) (MW) (MW)

A. State (Own) Generating Stations (SGS)

A.1 SHP Projects A.1.1 Likim Ro

(24 MW) RES

(MNRE) Nagaland 24.00 24.00 24.00 24.00 24.00

A.1.2 Duilum Roi Stage-I (0.54MW)

RES (MNRE)

Nagaland 0.54 0.54 0.54 0.54 0.54

A.1.3 Duilum Roi Stage-II (0.20MW)

RES (MNRE)

Nagaland 0.20 0.20 0.20 0.20 0.20

A.1.4 Telangsao (0.60MW)

RES (MNRE)

Nagaland 0.60 0.60 0.60 0.60 0.60 Not in Operation

A.1.5 Tsutha (0.75 MW)

RES (MNRE)


A.1.6 Dzuza (1 MW)

RES (MNRE)


A.1.7 Lang (1 MW)

RES (MNRE)

Nagaland 1.00 1.00 1.00 1.00 1.00

A.1.8 Tohok (1 MW)

RES (MNRE)

Nagaland 0.00 1.00 1.00 1.00 1.00 1 MW will be available from 01 Dec 2015

A.1.9 Zungki (24 MW)

RES (MNRE)

Nagaland 0.00 0.00 0.00 0.00 0.00 COD Beyond 2018-19

A.1.11 Tizu (15 MW)

RES (MNRE)


A.1.12 Ponglefo RES (MNRE)

Nagaland 0.00 0.00 0.00 0.00 1.00 1 MW will be available from FY 2018-19.

A.2 SGS Hydro A.2.1 Lower Tizu

(36 MW) Hydro (HEP)


A.3 SHP Projects(Under New and Renewable Energy Department)

A.3.1 SHP (1.1 MW)

RES (MNRE)

Nagaland 0.00 1.10 1.10 1.10 1.10 1.10 MW will be available from FY 2015-16.


Sl. No Power Sources/ Generating Stations

Type (Thermal/

Hydro/ RES etc.)


As on March 2015


FY 2015-

16

FY 2016-

17

FY 2017-

18

FY 2018-

19


A.3.2 SHP (0.45 MW)

RES (MNRE)


A.3.3 SHP (2.1 MW)

RES (MNRE)


A.3.4 SHP (6.6 MW)

RES (MNRE)


Sub Total SGS 28.09 30.19 30.64 32.74 40.34 B IPP (PRIVATE SECTOR) PROJECTS

B.1 SPV Projects

B.1.1 Ganesh Nagar Dimapur (20MW)

RES (MNRE)

Nagaland 0.00 0.00 20.00 20.00 20.00 20 MW will be available from FY 2016-17.

B.1.2 Zhadima, Kohima (10 MW)

RES (MNRE)

Nagaland 0.00 0.00 0.00 10.00 10.00 1 0 MW will be available from FY 2017-18.

B.1.3 Jalukie, Peren (30 MW)

RES (MNRE)

Nagaland 0.00 0.00 0.00 30.00 30.00 30 MW will be available from FY 2017-18

Sub Total IPP Projects 0.00 0.00 20.00 60.00 60.00 C Central Sector Power Generating Stations (CGS)

C.1 CGS Thermal

C.1.1 Farakka, NTPC (3X200 MW + 3X500 MW = 2100 MW)

Thermal (Coal)

West Bengal

11.20 11.20 11.20 11.20 11.20

C.1.2 Kahelgaon Stage I, NTPC (4X210 MW = 840MW)

Thermal (Coal)

Bihar 5.80 5.80 5.80 5.80 5.80

C.1.3 Talcher NTPC (6 X 500 MW=3000 MW)

Thermal (Coal)

Orissa 7.00 7.00 7.00 7.00 7.00

C.1.4 NTPC Bongaigon Thermal (3X250MW=750MW)

Thermal (Coal)

Assam 0.00 32.00 32.00 32.00 32.00 32 MW will be available from 01 Dec 2015

C.1.5 AGTPP NEEPCO (84MW)

Thermal (Gas)

Tripura 4.52 4.52 4.52 4.52 4.52


Sl. No Power Sources/ Generating Stations

Type (Thermal/

Hydro/ RES etc.)


As on March 2015


FY 2015-

16

FY 2016-

17

FY 2017-

18

FY 2018-

19


C.1.6 AGBPP NEEPCO (291 MW)

Thermal (Gas)

Assam 16.91 16.91 16.91 16.91 16.91

C.1.7 Palatana- I OTPC (1X363 MW)

Thermal (Gas)

Tripura 13.00 13.00 13.00 13.00 13.00

C.1.8 Palatana- II OTPC (1X363 MW)

Thermal (Gas)

Tripura 0.00 13.00 13.00 13.00 13.00 13 MW will be available from FY 2015-16

C.2 CGS Hydro C.2.1 Doyang NEEPCO

(75MW) Hydro (HEP)

Nagaland 13.48 13.48 13.48 13.48 13.48

C.2.2 Khandong NEEPCO (50MW)

Hydro (HEP)

Assam 3.33 3.33 3.33 3.33 3.33

C.2.3 Kopili -I NEEPCO (200 MW)

Hydro (HEP)

Assam 12.30 12.30 12.30 12.30 12.30

C.2.4 Kopili-II NEEPCO (25 MW)

Hydro (HEP)

Assam 0.00 0.00 0.00 0.00 0.00 Not in operation

C.2.5 Ranganadi, NEEPCO (405 MW)

Hydro (HEP)

Arunachal Pradesh

21.63 21.63 21.63 21.63 21.63

C.2.6 Loktah NHPC (3X35 MW)

Hydro (HEP)

Manipur 6.76 6.76 6.76 6.76 6.76

C.2.7 Lower Subansari HEP (2000MW)

Hydro (HEP)

Arunachal Pradesh

0.00 0.00 0.00 0.00 0.00 34 MW will be available beyond FY 2018-19

C.2.8 Kamen HEP (600MW)

Hydro (HEP)

Arunachal Pradesh

0.00 0.00 0.00 20.00 20.00 20 MW will be available from FY 2017-18

C.2.9 Pare HEP (110MW)

Hydro (HEP)

Arunachal Pradesh

0.00 0.00 20.00 20.00 20.00 20 MW will be available from FY 2016-17

C.2.10 Tapaimukh HEP (2X75 MW)

Hydro (HEP)

Manipur 0.00 0.00 0.00 0.00 0.00 COD Beyond 2018-19

Sub Total CGS 115.93 160.93 180.93 200.93 200.93

Grand Total of (A+B+C)

144.02 191.12 231.57 293.67 301.27


ANNEXURE-V

Existing Intra & Inter State Transmission System

LIST OF 132 kV & 66 kV S/STNS in NAGALAND as on 30.09.2015

Sl. No.

Name of Sub station 132/66 132/33 66/33 66/11 33/11 Total installed capacity in MVA

I DIMAPUR 1 Nagarjan 1x100 - 3x20 - 2x5 170

2 Dairy Farm - - 1x5 - 1x5 10

3 Nito Farm, Purana Bazar - - 1x5 - 1x1.6 6.6

4 Ganeshnagar 1x10 1x5 15

5 Chumukedima - - 1x10 1x20 - 30

6 Sovima 1x20 - 20

7 Power House, Burma Camp - - 2x10 1x5 25

II MOKOKCHUNG 8 Aolichen 2x25 - 2x7.5 - - 65

9 Tuli

- - 2x10 - - 20 10 - - 1x7.5 - - 7.5 III KIPHIRE 11 Kiphire 3x10 - 1x5 - - 35

IV WOKHA 12 Wokha - 2x5 - - 10

V KOHIMA 13 Kohima 3x8 - - 2x10 44

VI PHEK 14 Meluri 1x12.5 - - - 12.5

VIII MON 15 Naginimora 1x5 - 5

16 Mon 3x2.5 7.5

17 Tizit 1x5 5

IX TUENSANG 18 Tuensang - - 1x7.5 - - 7.5

X ZUNHEBOTO

19 Zunheboto - - 1x7.5 - - 7.5

Total Installed Capacity 503.1


Existing 66 KV & 132 kV lines as on 30.09.2015 Sl. No.

Name of Line No. of Ckts. Length (Ckt Kms)

66 kV Lines (Intra State) 1. Nagarjan(Dimapur) 132 KV SS to Power House (Dimapur)

66KV SS S/C 4

2. Nagarjan(Dimapur )132 KV SS to Singrijan D/C 10.8

3. Aolichen MKG 132 KV SS to Zunheboto 66 KV SS S/C 42.2

4. Aolichen MKG 132 KV SS to Tuli 66 KV SS S/C 56.3

5. Aolichen MKG 132 KV SS to Tuensang 66 KV SS S/C 50.38

6. Kiphire 132 KV SS to Likimro HEP D/C 70

7. Tuensang 66 KV SS to Kiphire 132 KV SS S/C 55.74

8. Power House(Dimapur) 66KV SS to Dairy Farm (Dimapur) 66KV SS

S/C 7

9. Dairy Farm(Dimapur) 66 KV SS to Nito Farm 66 KV SS S/C 12

10. Singrijan to Chumukedima 66 KV SS S/C 21.41

11. Singrijan to Ganeshnagar 66 KV SS S/C 14

12. Tuli 66 KV SS to Naganimara 66 KV SS S/C 33

13. Naganimora 66 KV SS to Tizit 66 KV SS S/C 30

14. Tizit 66 KV SS to Mon 66 KV SS S/C 40

446.83

66 kV Lines (Inter State)

15. Nagarjan(Dimapur) 132 KV SS to Bokajan Assam S/C 17

17

132 kV Lines (Intra State)

16. 132 KV SS Nagarjan Dimapur to 132 KV SS Kohima S/C 44.50

17. 132 KV SS Kohima to 132 KV SS Wokha S/C 56.33

18. 132 KV SS Kohima to 132 KV SS Meluri S/C 74.00 19. 132 KV SS Wokha to NEEPCO Doyang HEP S/C 27.00

20. 132 KV SS Meluri to 132 KV SS Kiphire S/C 42.00

243.83

132 kV Lines (Inter State)

21. 132 KV MKG to 220 KV SS Mariani(Assam) S/C 52.81

22. 132 KV Kohima- Karong(Manipur) S/C 50.00

23. 132 KV Doyang(NEEPCO) - MKG Line S/C 27.00

24. Dimapur 220 kV PGCIL to Dimapur 132 kV State S/C 1.00 130.81


ANNEXURE-VI

Year Wise Proposed Investment Plan for Intra State Transmission System

List of Planned Substations FY 2015-16

Sl. No.

District Name of substation

Capacity Addition (MVA) Tentative Cost in Rs lac

220/132 kV Level

132/33 kV level

132/11 kV level

66/11 kV level

Total

1 Kohima Kohima - 24 - - 24 3335 2 Dimapur Cricket Stadium

Sovima - - - 20 20 2812

Total : 24 20 6147

List of planned Substations FY 2016-17

Sl. No.



220/132 kV Level

132/33 kV level

132/11 kV level

66/11 kV level

Total

1

Kohima

Zhadima 100 20 - - 120 6858

2 Zhadima (Chiephobozou)

- 12.5 - - -

3 NH61 (Philimi) - 10 - - 10 3279.64

4 Wokha

Doyang Near NEEPCO Project (SANIS) with associated lines. (LILO)

- 12.5 - - 12.5 3544

Total : 55.00 13681.64

List of planned Substations FY 2018-19 Sl. No.



220/132 kV Level

132/33 kV level

132/11 kV level

66/11 kV level

Total

1

Dimapur

Razaphema (Green field Airport)

- - 12.5 - 12.5 2241

2 Rangapahar - 100 - - 100 3900 Total : 100 12.5 6141


List of planned Substations under NERPSIP Funding

Sl. No.


Capacity Addition (MVA)

220/132 kV Level

132/33 kV level

132/11 kV level

66/11 kV level

Total

1 Wokha Wokha - 25 - - 25 2 Mokokchung Longnak - 50 - - 50 3 Longleng Longleng - 20 - - 20 4 Zunheboto Zunheboto - 50 - - 50 5

Kohima Secretariat Complex

- 50 - - 50

6 Phek Pfutsero - 50 - - 50 Total : 245 245

List of planned Substations to undergo Bay Extension to accommodate New Lines

Sl. No. District Name of substation Voltage Level Tentative

Cost in Rs lac 1 Kohima New Kohima 220 kV 212.05 2 Tuensang Tuensang 132 kV 189.07 3 Kohima New Kohima 220 & 132 kV 212.05 4 New Kohima 220 & 132 kV 235.8 5 New Kohima 220 & 132 kV 267.02 6 Mokokchung Mokokchung 132 & 33 kV 181.06 7 Wokha Wokha 132 & 33 kV 147.13 1444.18

List of Planned Transmission Lines FY 2015-16

Sl. No. Line Section Line

Length (Ckt.Kms)

Tentative Cost Rs

in Crs.

Tentative Completion

Schedule 132 kV Lines

1 Up gradation from 66 kV to 132 kV KPRE-TSNG-MKG Transmission Line – Phase – I (S/C)

56.30 4.9 2015-16

2 132 kV SS Sanis (under construction) to Wokha – Dovang LILO point (D/C)

11.40 6.5 2015-16

3 Restoration of Doyang HEP-Wokha S/C 16.90 11.03 2015-16 Total : 84.6 22.43 66 kV Lines

1 Sovima Cricket Ground 66 KV SS to LILO pt of Singrijan-Chumukedima (D/C)

5 2.12 2015-16

2 Ganeshnagar 66 KV SS to Peren 66KV SS (S/C) 50 25.48 2015-16 Total : 55 27.60



Sl. No. Line Section Line Length

(Ckt.Kms)

Tentative Cost Rs

in Crs.



1 132 kV SS Wokha – 132 kV Doyang NH61 (S/C) 20.77 28.50 2016-14 Total : 20.77 28.50



(Ckt.Kms)

Tentative Cost Rs

in Crs.



1 Dimapur – Zhadima (D/C) 69 87.68 Total : 69 87.68 132 kV Lines

1 Upgradation from 66 kV to 132 kV KPRE – TSNG – MKG Transmission Line Phase – II (S/C)

48.71 5.94

Total : 48.71 5.94



(Ckt.Kms)

Tentative Cost Rs

in Crs.



1 Razaphema Greenfield Airport to LILO point of DMR-KMA 132 kV Line (Jarnapani) (S/C)

13.4 17.35

2 Dimapur (Nagarjan) – Rangapahar (S/C) 10 12.99 Total : 23.4 30.34

List of Planned Transmission Lines under NERPSIP Funding

Sl. No.

Line Section Line Length (Ckt.Kms)

Tentative Cost Rs in Crs.

220 kV Lines 1 New Kohima to MKG PGCIL (S/C) 92 183.46 Total : 92 132 kV Lines

1 Wokha – Zunheboto – Mokokchung (S/C on D/C Tower) 97 2 Tuensang – Longleng (S/C on D/C Tower) 36 3 New Zhadima to Sectt. Kohima (D/C) 56 4 New Zhadima to LILO at KMA-WKA (D/C) 30 5 Pfutsero to LILO of at KMA-Meluri (D/C) 32 6 Longnak to LILO at MKG-MRNI (D/C) 1 Total : 252


ANNEXURE-VII-A

Details of POWERGRID Lines in Nagaland

Sl. No.

Name of the Line Length in ckt km Voltage Level in kV

1. Misa to Dimapur 248 220 2. Maraiani (New) to Mokokchung 100 220 3. Doyang to Dimapur 186 132 4. Dimapur to Imphal 169 132 5. 132 KV MKG to 220 KV MKG (PGCIL) 4 132 6. 132 KV Dimapur-PGCIL Dimapur 10 132 7. Dimapur – kohima (LILO) 10 132

727


ANNEXURE-VII-B

POWERGRID IN NAGALAND (Existing Transmission line details and Proposed Substations & lines) A) Existing transmission facilities:

POWERGRID has following transmission system in Nagaland:

220 kV Transmission Lines : About 348 CKm 132 kV transmission lines : About 379 CKm 220/132 kV Substations : 1 (Dimapur) (Est. Capacity: 200 MVA)

1(Mokokchung) (Est. Capacity: 60 MVA)

B) Ongoing/Proposed Schemes

POWERGRID has undertaken/planned a number of transmission works in Nagaland to strengthen the connectivity of Nagaland State Grid with National Grid.

Some of the major works are as given below: i. Bay Addition at Mokokchung

220 kV Bay Extension is planned in Mokokchung 220/132 kV Substation. The Project Cost is Rs. 1665.9 Lacs.

ii. Augmentation of transformation capacity in Nagaland

• To meet the growing power demand of Nagaland, POWERGRID has taken up augmentation of transmission capacity in 220 kV Mokokchung substations. This would enable Nagaland to draw its enhanced share of power from the Grid.

iii. Future system strengthening by TBCB Schemes. (NERSS – VI) • Imphal to New Kohima 400 kV D/C 240 CKm Transmission Line. • New Kohima to New Mariani 400 kV D/C 220 CKm Transmission Line. • Setting up of 400/220 kV 2X500 MVA Substation at New Kohima.

C) Issues

A comprehensive scheme for strengthening of transmission, sub-transmission and distribution system in NER & Sikkim has been evolved by CEA in consultation with respective states and POWERGRID. Funding for implementation of the intra-State transmission, sub-transmission (132kV and above) as well as distribution scheme (33kV and above) is being pursued by Ministry of Power, Govt. of India with The World Bank. The World Bank has proposed to provide assistance of US $ 1500 Million in three tranches of US $ 500 Million each. Accordingly, the transmission and distribution works covered in the DPR has been prioritized to match with the first tranche (US $ 500 Million) of the proposed World Bank Assistance. Broad scope for transmission system in Nagaland includes 5 nos. new 132/33 kV sub-stations (245 MVA) and about 376 Ckm. Transmission lines at 220 & 132 kV level.


ANNEXURE-VIII - A DISTRICT WISE OVERALL PLAN AND FUND REQUIREMENT AGAINST ONGOING PROJECTS UNDER 12TH PLAN RGGVY

IN 11 DISTRICTS OF NAGALAND

Sl. No.

Item of Work Unit

DIMAPUR KOHIMA PHEK WOKHA MOKOKCHUNG TUENSANG

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

1 New 33/11 KV 1x2.5 MVA, 33/11KV No 1 315.90 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 2 Augmentation of SS

2.1 1x5MVA No 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 2.2 1x2.5 MVA No 0 0.00 0 0.00 0 0.00 0 0.00 1 48.27 0 0.00

Total MVA 2.5 0 0 0 2.5 0 3 New Feeders/Lines

3.1 New 33KV Feeder Km 28 573.76 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 3.2 Reconductoring of 33KV Feeder Km 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 3.3 New 11KV Feeder Km 7 74.29 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 3.4 Reconductoring of 11KV Feeder Km 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 3.5 33KV Spur Line for DTs Km 8 163.93 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 3.6 11KV Spur line for DTs Km 22.3 236.67 19.9 211.14 28.3 300.47 41.9 444.74 17.7 187.52 12.8 135.93 4 Distribution Transformers (New)

4.1 16 KVA No 0 0.00 1 3.87 0 0.00 0 0.00 2 7.73 2 7.73 4.2 25 KVA No 37 148.19 22 95.03 19 83.25 32 125.68 18 73.57 6 23.56 4.3 63 KVA No 10 43.44 5 21.72 3 13.03 4 17.38 1 4.34 2 8.69

Total MVA 1.56 0.88 0.66 1.05 0.55 0.31 5 LT Line Km 28.9 242.00 24.3 203.10 24.6 205.58 28.6 239.60 21.1 176.68 6.49 54.30 6 Service connection to BPL No 6963 208.89 1737 52.11 2880 86.40 4754 142.62 2477 74.31 3302 99.06

2007.06 586.96 688.73 970.01 572.43 329.27


ANNEXURE-VIII - A

Contd…

Sl. No.

Item of Work Unit

MON ZUNHEBOTO LONGLENG PEREN KIPHIRE TOTAL

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

1 New 33/11 KV 1x2.5 MVA, 33/11KV No 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 1 315.899 2 Augmentation of SS

2.1 1x5MVA No 0 0.00 1.00 183.60 0 0.00 0 0.00 1 183.6 2.2 1x2.5 MVA No 0 0.00 2 109.41 0 0.00 0 0.00 0 0.00 3 157.673

Total MVA 0 5 5 0 0 15 3 New Feeders/Lines

3.1 New 33KV Feeder Km 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 28 573.758 3.2 Reconductoring of 33KV Feeder Km 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 3.3 New 11KV Feeder Km 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 7 74.2901 3.4 Reconductoring of 11KV Feeder Km 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 3.5 33KV Spur Line for DTs Km 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 8 163.931 3.6 11KV Spur line for DTs Km 28.1 297.94 29.5 312.73 8.61 91.47 40.2 426.82 17.9 190.09 267.1 2835.5 4 Distribution Transformers (New)

4.1 16 KVA No 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 5 19.3292 4.2 25 KVA No 31 130.38 11 43.20 14 60.74 30 120.70 5 19.64 225 923.93 4.3 63 KVA No 2 8.69 25 108.60 4 17.38 9 39.09 4 17.38 69 299.727

Total MVA 0.90 1.85 0.60 1.32 0.38 10.1 5 LT Line Km 29.6 247.58 23.8 199.18 21.9 182.90 20.9 175.21 11.1 92.53 241.3 2018.67 6 Service connection to BPL No 2227 66.81 6397 191.91 449 13.47 4851 145.53 3277 98.31 39314 1179.42

751.39 965.02 549.55 907.35 417.94 8745.72


ANNEXURE-VIII - B DISTRICT WISE OVERALL PLAN AND FUND REQUIREMENT AGAINST ONGOING PROJECTS UNDER NERPSIP DMS SCHEME


Sl. No.

Item of Work Unit

Dimapur Kohima Phek Wokha Mokokchung Tuensang

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

A. Feeder Separation 1 New 33KV Bay No 1 51.25 0 0.00 0 0.00 0 0.00 2 143.21 0 0.00

B. Strengthening of Sub-Transmission and Distribution Network 1 New 33/11 KV or 66/11 KV SS :

1.1 2x10 MVA, 33/11KV No 1 595.16 0 0.00 0 0.00 0 0.00 1 595.16 0 0.00 1.2 2x5 MVA, 33/11KV

0 0.00 1 530.64 1.00 530.64

2 1061.28 0 0.00

1.3 2x2.5 MVA, 33/11KV

0 0.00 1 462.76 0 0.00 0 0.00 0 0.00 0 0.00 2 Augmentation of SS

2.1 2x 10 MVA, 33/11KV No 0 0.00 1 320.67 0 0.00 0 0.00 0 0.00 0 0.00 2.2 1x10 MVA, 33/11KV No 2 448.69

0 0.00 0 0.00 0 0.00 0 0.00

2.3 1x5MVA No

3 576.10 0 0.00 2 384.06 2 384.06 0 0.00

Total MVA 40

50

10

10

50

0

4 New Feeders/Lines

New 33KV Feeder Km 10 244.76 1 21.26 4.00 85.03 0 0.00 30.5 660.73 0 0.00 C. OPGW/ADSS

1 OPGW/ADSS Km 30 99.75 15 49.88 4.00 13.30 0 0.00 80.5 267.67 67.00 222.78

1439.61

1961.30

628.97

384.06

3112.11

222.78


ANNEXURE-VIII - B Contd…

Sl. No.

Item of Work Unit


Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

A. Feeder Separation 1 New 33KV Bay No

4 205.01

7 399.47


1.1 2x10 MVA, 33/11KV No

2 1190.32 1.2 2x5 MVA, 33/11KV

1 494.08 1 530.64 1 530.64

7 3677.90

1.3 2x2.5 MVA, 33/11KV

1 462.76 2 Augmentation of SS

2.1 2x 10 MVA, 33/11KV No

1 320.67

2.2 1x10 MVA, 33/11KV No

2 448.68 2.3 1x5MVA No

2 384.06

9 1728.29

Total MVA 10

20

10

0

0

200

4 New Feeders/Lines

New 33KV Feeder Km

26 552.68 5.00 106.28

76.5 1670.74 C. OPGW/ADSS

1 OPGW/ADSS Km

32 106.40 5.00 16.63

233.5 776.4

494.08

1778.80

653.55

0.00

0.00

10675.25


ANNEXURE-VIII - C DISTRICT WISE OVERALL PLAN AND FUND REQUIREMENT AGAINST ONGOING PROJECTS UNDER DDUGJY


Sl. No.

Item of Work Unit


Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

1 New Feeders/Lines

11KV Spur line for DTs Km 8.1 114.70 4.75 67.26 1.5 21.24 18.7 264.08 5.4 76.46 35.5 501.97

2 Distribution Transformers (New)

2.1 25 KVA No 6 31.21 2 10.40 2 10.40 11 57.22 2 10.40 13 67.63

2.2 63 KVA No 0 3 20.52 0.00 5 34.20 3 20.52 5 34.20

2.3 100 KVA No 2 Total MVA 0.35 0.24 0.05 0.59 0.24 0.64

3 LT Line Km 11.3 124.43 4.95 54.75 1.78 19.63 29.2 322.73 5.9 65.25 11.3 124.43

4 Service connection to BPL

No 554 16.62 56 1.68 150 4.50 722 21.66 178 5.34 1299 38.97

286.95 154.61 55.78 699.90 177.98 767.19


ANNEXURE-VIII - C Contd…

Sl. No.

Item of Work Unit


Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

1 New Feeders/Lines

11KV Spur line for DTs Km 34.7 491.35 0 0.00 3.05 43.19 49.8 704.46 4.9 69.38 166.3 2354.10


2.1 25 KVA No 8 41.62 0 0.00 0 0.00 12 62.43 3 15.61 59 306.93 2.2 63 KVA No 1 6.84 0 0.00 3 20.52 3 20.52 0.00 23 157.31 2.3 100 KVA No 2 0

Total MVA 0.26 0.00 0.19 0.49 0.08 3.12

3 LT Line Km 12.7 140.74 0 0.00 4.76 52.59 13.2 146.27 1.4 15.48 96.41 1066.29 4 Sevice connection to BPL No 622 18.66 0 0.00 167 5.01 760 22.80 235 7.05 4743 142.29

699.21 0.00 121.31 956.47 107.52 4026.92


ANNEXURE-IX - A DISTRICT WISE OVERALL PLAN AND FUND REQUIREMENT AGAINST FUTURE PROJECTS UNDER IPDS SCHEME

IN 12 TOWNS OF 11 DISTRICTS OF NAGALAND

Sl. No.

Item of Work Unit


Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in

Lakh) A. Strengthening of Sub-Transmission and Distribution Network

1 New 33/11 KV or 66/11 KV SS : 1.1 2x10 MVA, 33/11KV No 2 1851.70 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 1.2 1x10 MVA, 33/11 KV No 0 0.00 1 544.99 0 0.00 0 0.00 0 0.00 0 0.00 1.3 1x5 MVA, 33/11KV No 0 0.00 0 0.00 1 467.85 0 0.00 0 0.00 0 0.00 2 Augmentation of SS

2.1 1x10 MVA, 33/11KV No 2 919.96 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 2.2 1x5MVA No 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 1.00 360.66 2.3 1x2.5 MVA No 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00

Total MVA 60 10 5 0 0 5

3 R&M works in existing 33/11 KV or 66/11 KV substations

No. 4 462.01 1 95.22 0 0.00 0 0.00 0 0.00 1 202.39

4 New Feeders/Lines 4.1 New 33KV Feeder Km 9 410.46 4 152.10 20.00 369.78 0 0.00 0 0.00 0 0.00 4.2 Reconductoring of 33KV Feeder Km 20 421.08 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 4.3 New 11KV Feeder Km 50 1881.17 4 148.06 1 14.08 1.5 21.13 1.2 51.91 0 0.00 4.4 Reconductoring of 11KV Feeder Km 9 153.92 4.5 11KV Spur line for DTs Km 55.9 871.17 17 264.93 2.6 36.62 4.7 66.19 4.2 59.15 5 70.42 5 Distribution Transformers

5.1 New DTs


Sl. No.

Item of Work Unit


Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in

Lakh) 5.1.1 100 KVA No 15 140.97 0 0.00 1 9.40 6 56.39 6 56.39 3 28.19 5.1.2 250 KVA No 78 1159.40 24 356.74 2 29.73 0 0.00 0 0.00 2 29.73

5.1.3 500 KVA No 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00

5.2 Augmentation of DTR

5.2.1 100 KVA No. 0 0.00 0 0.00 1 6.42 0 0.00 0 0.00 0 0.00

5.2.2 250KVA. No. 16 189.71 1 11.86 2 23.71 3 35.57 2 23.71 0 0.00

5.2.3 500 KVA No. 34 576.43 6 101.72 0 0.00 0 0.00 1 16.95 0 0.00 Total MVA 42 9.25 1.2 1.35 1.6 0.8

6 LT Line Km 93.10 1381.12 31.00 459.88 3.00 37.56 4.70 58.84 4.80 60.09 5.00 62.60

7 R&M of DTs Nos 93 281.89 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00

B. Metering 1 SS & Feeder Nos 13 39.54 10 30.53 0 0.00 4 12.44 9 28.25 4 11.56 2 Distribution Transformer Nos 202 146.75 7 5.09 0 0.00 0 0.00 10 7.26 0 0.00 3 Consumer

3.1 Prepaid meters Nos 18591 2168.56 1030

0 1190.40 0 0.00 0 0.00 0 0.00 0 0.00

3.2 1Ph LT Electronic meters Nos 16200 486.00 9000 270.00 1500 45.00 2000 60.00 1000 30.00 3000 90.00

4 Relocation of inaccessible meters

Nos 10000 800.00 5000 400.00 100 8.00 100 8.00 100 8.00 100 8.00

C. Roof Top Solar Panel at SS Nos 9 22.50 3 7.50 0 0.00 1 2.50 1 2.50 2 5.00

14364.33 4039.01 1048.15 321.06 344.23 868.56


ANNEXURE-IX - A

Contd…

Sl. No.

Item of Work Unit


Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

A. Strengthening of Sub-Transmission and Distribution Network

1 New 33/11 KV or 66/11 KV SS 1.1 2x10 MVA, 33/11KV No 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 2 1851.70

1.2 1x10 MVA, 33/11 KV No 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 1 544.99

1.3 1x5 MVA, 33/11KV No 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 1 467.85

2 Augmentation of SS 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00

2.1 1x10 MVA, 33/11KV No 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 2 919.96

2.2 1x5MVA No 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 1 360.66

2.3 1x2.5 MVA No 1 342.51 0 0.00 0 0.00 1 342.51 0 0.00 2 685.03 Total MVA 2.5 0 0 2.5 0 85


No. 1 92.01 0 0.00 0 0.00 0 0.00 0 0.00 7 851.63

4 New Feeders/Lines 4.1 New 33KV Feeder Km 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 33.00 932.34

4.2 Reconductoring of 33KV Feeder

Km 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 20.00 421.08

4.3 New 11KV Feeder Km 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 57.70 2116.35


Km 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 9.00 153.92

4.5 11KV Spur line for DTs Km 2.75 38.73 2.5 35.21 3 42.25 4 56.33 4 56.33 105.65 1597.34


Sl. No.

Item of Work Unit


Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

5 Distribution Transformers 5.1 New DTs

5.1.1 100 KVA No 3 28.19 3 28.19 3 28.19 2 18.80 2 18.80 44 413.52

5.1.2 250 KVA No 0 0.00 3 44.59 0 0.00 2 29.73 2 29.73 113 1679.64

5.1.3 500 KVA No 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00


5.2.1 100 KVA No. 3 19.27 0 0.00 1 6.42 0 0.00 0 0.00 5 32.12

5.2.2 250KVA. No. 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 24 284.56

5.2.3 500 KVA No. 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 41 695.10 Total MVA 0.6 1.05 0.4 0.7 0.7 59.65

6 LT Line Km 7.85 98.28 2.00 25.04 6.00 75.12 7.00 87.64 7.00 87.64 171.45 2433.81

7 R&M of DTs Nos 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 93 281.89

B. Metering 1 SS & Feeder Nos 5 15.26 10 30.53 9 27.70 8 24.88 12 37.93 84 258.62 2 Distribution Transformer Nos 0 0.00 0 0.00 17 12.35 11 7.99 9 6.54 256 185.98 3 Consumer

3.1 Prepaid meters Nos 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 28891 3358.96

3.2 1Ph LT Electronic meters Nos 1500 45.00 2000 60.00 1630 48.90 900 27.00 1000 30.00 39730 1191.90

4 Relocation of inaccessible meters Nos

100 8.00 100 8.00 100 8.00 50 4.00 50 4.00 15800 1264.00

C. Roof Top Solar Panel at SS Nos 1 2.50 1 2.50 1 2.50 0 0.00 1 2.50 20 50.00

689.76

234.06

251.44

598.88

273.46

23032.94


ANNEXURE-IX – B

DISTRICT WISE OVERALL PLAN AND FUND REQUIREMENT AGAINST FUTURE PROJECTS UNDER DDUGJY IN 11 DISTRICTS OF NAGALAND

Sl. No.

Item of Work Unit


Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

A. Feeder Separation 1 New 33KV Bay No 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 1.00 9.75 2 New 11KV Bay No 2 16.47 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 3 New 33KV Line Kms. 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 33.00 522.39 4 New 11KV Line Kms. 35.00 495.60 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 5 LT Line KMs

B. Strengthening of Sub-Transmission and Distribution Network 1 New 33/11 KV SS :

1.1 1x2.5 MVA, 33/11KV No 0 0.00 1 359.61 0 0.00 1 342.51 0 0.00 0 0.00 1.2 1x 1.6MVA, 33/11KV No 0 0.00 0 0.00 0 0.00 0 0.00 1 152.11 1 152.11 1.3 1x 0.5 MVA, 33/11KV No 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 1 140.06 2 Augmentation of SS

2.1 1x2.5 MVA No 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 2.2 1x1.6 MVA No 0 0.00 0 0.00 0 0.00 0 0.00 2 191.64 0 0.00

Total MVA 0 2.5 0 2.5 4.8 2.1 3 New Feeders/Lines

3.1 New 33KV Feeder Km 0 0.00 0.50 7.92 0 0.00 20.00 316.60 10.00 158.30 25.50 403.67 3.2 New 11KV Feeder Km 0 0.00 3.00 42.48 0 0.00 1.50 21.24 3.00 42.48 10.50 148.68 3.3 11KV Spur line for DTs Km 96.80 1370.69 39.65 561.44 63.80 903.41 26.50 375.24 43.15 611.00 42.15 596.84 4 Distribution Transformers


Sl. No.

Item of Work Unit


Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

4.1 New DTs 4.1.1 25 KVA No 66 343.33 15 78.03 32 166.46 20 104.04 26 135.25 26 135.25 4.1.2 63 KVA No 21 143.62 15 102.59 20 136.78 7 47.87 10 68.39 21 143.62 4.1.3 100 KVA No 5 38.60 0 0.00 2 15.44 0 0.00 2 15.44 1 7.72 4.2 Augmentation of DTR

4.2.1 25KVA No. 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 2 6.52 4.2.2 63 KVA No. 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 6 29.03 4.2.3 250KVA. No. 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00

Total MVA 3.473 1.32 2.26 0.941 1.48 2.501 5 LT Line Km 179.00 1908.14 77.80 829.35 56.10 598.03 35.80 381.63 46.70 497.82 27.70 295.28 6 R&M of DTs Nos 71 8.28 77 8.98 45 5.25 26 3.03 69 8.04 35 4.08 7 Service connection to BPL No 8007 240.21 4091 122.73 6140 184.20 3993 119.79 5621 168.63 7751 232.53

C. Metering 1 SS & Feeder Nos 14 41.10 9 26.19 15 43.65 25 71.31 37 107.31 32 92.40 2 Distribution Transformer Nos 402 291.85 117 84.94 80 58.08 136 98.74 141 102.37 229 166.25 3 Consumer Nos

1Ph LT Electronic meters Nos 22647 634.12 18994 531.83 19573 548.04 15816 442.85 19401 543.23 14389 402.89 5532.01 2756.09 2659.34 2324.85 2802.02 3489.08


ANNEXURE-IX - B Contd…

Sl. No.

Item of Work Unit


Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

A. Feeder Separation 1 New 33KV Bay No 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 1 9.75 2 New 11KV Bay No 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 2 16.47 3 New 33KV Line Kms. 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 33.00 522.39 4 New 11KV Line Kms. 0 0.00 0 0.00 0 0.00 26.00 368.16 0 0.00 61.00 863.76 5 LT Line KMs 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00

B. Strengthening of Sub-Transmission and Distribution Network 1 New 33/11 KV SS :

1.1 1x2.5 MVA, 33/11KV No 1 342.51 2 719.23 0 0.00 1 342.51 0 0.00 6 2106.38 1.2 1x 1.6MVA, 33/11KV No 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 2 304.21 1.3 1x 0.5 MVA, 33/11KV No 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 1 140.06 2 Augmentation of SS

2.1 1x2.5 MVA No 1 335.39 0 0.00 0 0.00 0 0.00 1 241.44 2 576.83 2.2 1x1.6 MVA No 0 0.00 0 0.00 0 0.00 0 0.00 0 0.00 2 191.64

Total MVA 5 5 0 2.5 2.5 26.9 3 New Feeders/Lines

3.1 a). New 33KV Feeder Km 18.00 284.94 17.00 269.11 0 0.00 25.00 395.75 0 0.00 116.00 1836.28 3.2 c).New 11KV Feeder Km 6.00 84.96 10.50 148.68 0 0.00 4.50 63.72 0 0.00 39.00 552.24 3.3 f)). 11KV Spur line for DTs Km 75.30 1066.25 95.25 1348.74 17.30 244.97 75.10 1063.42 23.50 332.76 598.50 8474.76 4 Distribution Transformers

4.1 New DTs 4.1.1 25 KVA No 62 322.52 79 410.96 23 119.65 37 192.47 13 67.63 399 2075.60 4.1.2 63 KVA No 13 88.91 34 232.53 0 0.00 5 34.20 16 109.42 162 1107.92


Sl. No.

Item of Work Unit


Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

Qty Amt.

(in Lakh) Qty

Amt. (in Lakh)

4.1.3 100 KVA No 1 7.72 0 0.00 0 0.00 0 0.00 3 23.16 14 108.08 4.2 Augmentation of DTR

4.2.1 25KVA No. 0 0.00 0 0.00 0 0.00 1 3.26 0 0.00 3 9.77 4.2.2 63 KVA No. 0 0.00 1 4.84 0 0.00 1 4.84 0 0.00 8 38.71 4.2.3 250KVA. No. 0 0.00 0 0.00 0 0.00 0 0.00 1 10.81 1 10.81

Total MVA 2.469 4.18 0.575 1.328 1.883 22.41 5 LT Line Km 63.80 680.11 95.00 1012.70 24.99 266.39 54.60 582.04 23.06 245.82 684.55 7297.30 6 R&M of DTs Nos 44 5.13 43 5.01 20 2.33 16 1.87 27 3.15 473 55.15 7 Service connection to BPL No 6934 208.02 6815 204.45 1744 52.32 3916 117.48 1548 46.44 56560 1696.80

C. Metering 1 SS & Feeder Nos 19 54.66 15 44.46 9 25.92 8 23.37 8 23.10 191 553.47 2 Distribution Transformer Nos 264 191.66 272 197.47 100 72.60 89 64.61 136 98.74 1966 1427.32 3 Consumer Nos

1Ph LT Electronic meters Nos 18866 528.25 8232 230.50 5345 149.66 4246 118.89 4114 115.19 151623 4245.44 4201.04 4828.67 933.84 3376.58 1317.66 34221.16


ANNEXURE-IX - C THE SUMMARY OF OVERALL PLAN AGAINST FUTURE PROJECTS

Sl. No. Item of Work Unit IPDS DDUGJY

Net Qty Amt.(in Lakh) Net Qty Amt.(in Lakh)

A. Feeder Separation 1 New 33KV Bay No. 1 9.75 2 New 11KV Bay No. 2 16.47 3 New 33KV Line Km 33 522.39 4 New 11KV Line Km 61 863.76


1.1 2x10 MVA, 33/11KV No. 2 1851.70 1.2 1x10 MVA, 33/11 KV No. 1 544.99 1.3 1x5 MVA, 33/11KV No. 1 467.85 1.4 1x2.5 MVA, 33/11KV No. 6 2106.38 1.5 1x 1.6MVA, 33/11KV No. 2 304.21 1.6 1x 0.5 MVA, 33/11KV No. 1 140.06 2 Augmentation of SS

2.1 1x10 MVA, 33/11KV No. 2 919.96 2.2 1x5MVA No. 1 360.66 2.3 1x2.5 MVA No. 2 685.03 2 576.83 2.4 1x1.6 MVA No. 2 191.64 3 Brief Scope of R&M works in existing 33/11 KV or 66/11 KV substations No. 7 851.63 4 New Feeders/Lines

4.1 New 33KV Feeder Km 33 932.34 116 1836.28 4.2 Reconductoring of 33KV Feeder Km 20 421.08 4.3 New 11KV Feeder Km 57.7 2116.35 39 552.24 4.4 Reconductoring of 11KV Feeder Km 9 153.92


Sl. No. Item of Work Unit IPDS DDUGJY

Net Qty Amt.(in Lakh) Net Qty Amt.(in Lakh)

4.5 11KV Spur line for DTs Km 105.7 1597.34 598.5 8474.76 5 Distribution Transformers

5.1 New DTs 5.1.1 25 KVA No. 399 2075.60 5.1.2 63 KVA No. 162 1107.92 5.1.3 100 KVA No. 44 413.52 14 108.08 5.1.4 250 KVA No. 113 1679.64 5.2 Augmentation of DTR

5.2.1 25KVA No. 3 9.77 5.2.2 63 KVA No. 8 38.71 5.2.3 100 KVA No. 5 32.12 5.2.4 250KVA. No. 24 284.56 1 10.81 5.2.5 500 KVA No. 41 695.10

6 LT Line Km 171.5 2433.81 684.55 7297.30 7 R&M of DTs No. 93 281.89 473 55.15 8 Sevice connection to BPL No. 56560 1696.80

C. Metering 1 SS & Feeder No. 84 258.62 191 553.47 2 Distribution Transformer No. 256 185.98 1966 1427.32 3 Consumer

3.1 Prepaid meters No. 28891 3358.96 3.2 1Ph LT Electronic meters 39730 1191.90 151623 4245.44 4 Relocation of inaccessible meters 15800 1264.00

D. Roof Top Solar Panel at SS No. 20 50.00 TOTAL 23032.94 34221.16


ANNEXURE-X YEARWISE PROPOSED INFRASTRUCTURE PLAN FOR ALREADY SANCTIONED 12TH PLAN RGGVY

Sl. No.

Item of Work Unit DMP Year wise Roll Out Plan KHM Year wise Roll Out Plan PHEK Year wise Roll Out Plan

Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18

1 New 33/11 KV or 66/11 KV SS 1x2.5 MVA, 33/11KV No 1 1 2 Augmentation of SS

2.1 1x5MVA No 2.2 1x2.5 MVA No

Total MVA 2.5 0 0 3 New Feeders/Lines

3.1 New 33KV Feeder Km 28 8 20 3.2 New 11KV Feeder Km 7 5 2 3.3 33KV Spur Line for DTs Km 8 4 4 0 0 3.4 11KV Spur line for DTs Km 22.3 10 12.3 19.88 9 10.88 28.29 11.316 16.974


4.1 16 KVA No 1 1 0 0 4.2 25 KVA No 37 15 22 22 9 13 19 9 10 4.3 63 KVA No 10 10 0 5 5 0 3 3 0

Total MVA 1.555 0.881 0.664 5 LT Line Km 28.92 10 18.92

24.27 9 15.27

24.57 9 15.57

6 Service connection to BPL No 6963 2500 4463 1737 600 1137 2880 1152 1728


ANNEXURE-X Contd…

Sl. No.

Item of Work Unit WKH Year wise Roll Out Plan MKG Year wise Roll Out Plan TNSG Year wise Roll Out Plan

Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18 1 New 33/11 KV or 66/11 KV SS 1x2.5 MVA, 33/11KV No 0 0 0 2 Augmentation of SS

2.1 1x5MVA No 0 2.2 1x2.5 MVA No 0 1 1

Total MVA 0 2.5 0

3 New Feeders/Lines 3.1 New 33KV Feeder Km 3.2 New 11KV Feeder Km 3.3 33KV Spur Line for DTs Km 0 0 0 3.4 11KV Spur line for DTs Km 41.88 17 24.88 17.66 7 10.66 12.8 5.12 7.68


4.1 16 KVA No 0 2 2 2 2 4.2 25 KVA No 32 13 19 18 7 11 6 2 4

4.3 63 KVA No 4 4 0 1 1 0 2 2 Total MVA 1.052 0.545 0.308 5 LT Line Km 28.64 11.456 17.184

21.12 9 12.12

6.49 2.596 3.894

6 Sevice connection to BPL No 4754 1901.6 2852.4 2477 990 1487 3302 1320.8 1981.2


ANNEXURE-X Contd…

Sl. No.

Item of Work Unit MON Year wise Roll Out Plan ZHB Year wise Roll Out Plan LGLG Year wise Roll Out Plan

Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18 1 New 33/11 KV or 66/11 KV SS 1x2.5 MVA, 33/11KV No 0 0 0

2 Augmentation of SS 0 2.1 1x5MVA No 0 1.00 1 2.2 1x2.5 MVA No 0 2 1 1 0

Total MVA 0 5 5

3 New Feeders/Lines 3.1 New 33KV Feeder Km 3.2 New 11KV Feeder Km 3.3 33KV Spur Line for DTs Km 0 0 0 3.4 11KV Spur line for DTs Km 28.1 11.24 16.86 29.45 12 17.45 8.61 4 4.61


4.1 16 KVA No 0 0 0 4.2 25 KVA No 31 13 18 11 5 6 14 6 8

4.3 63 KVA No 2 2 0 25 10 15 4 2 2 Total MVA 0.901 1.85 0.602 5 LT Line Km 29.6 12 17.6 23.81 11 12.81 21.86 9 12.86 6 Service connection to BPL No 2227 890 1337 6397 2558.8 3838.2 449 180 269


ANNEXURE-X Contd…

Sl. No.

Item of Work Unit PRN Year wise Roll Out Plan KPHR Year wise Roll Out Plan TOTAL Year wise Roll Out Plan

Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18 1 New 33/11 KV or 66/11 KV SS 1x2.5 MVA, 33/11KV No 1 0 1 0 2 Augmentation of SS

2.1 1x5MVA No 0 0 0 1 0 1 0 2.2 1x2.5 MVA No 0 3 1 2 0

Total MVA 0 0 15 2.5 12.5 0 3 New Feeders/Lines

3.1 New 33KV Feeder Km 28 8 20 0 3.2 New 11KV Feeder Km 7 5 2 0 3.3 33KV Spur Line for DTs Km 8 4 4 0 3.4 11KV Spur line for DTs Km 40.19 17 23.19 17.9 7 10.9 267.06 110.676 156.384 0


4.1 16 KVA No 0 0 5 5 0 0 4.2 25 KVA No 30 12 18 5 2 3 225 93 132 0 4.3 63 KVA No 9 4 5 4 2 2 69 43 26 0

Total MVA 1.317 0.377 10.052 5.114 4.938 0 5 LT Line Km 20.94 9 11.94 11.06 4 7.06 241.28 96.052 145.228 0 6 Service connection to BPL No 4851 1940.4 2910.6 3277 1310.8 1966.2 39314 15344.4 23969.6 0


ANNEXURE-X YEARWISE PROPOSED INFRASTRUCTURE PLAN FOR ALREADY SANCTIONED DDUGJY

Sl. No.


Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18

1 New Feeders/Lines

11KV Spur line for DTs Km 8.1 2.43 5.67 4.75 1.425 3.325 1.5 0.75 0.75


2.1 25 KVA No 6 2 4 2 1 1 2 1 1

2.2 63 KVA No 0 3 1 2

2.3 100 KVA No 2 2

Total MVA 0.35 0.239 0.05

3 LT Line Km 11.25 3.375 7.875 4.95 1.485 3.465 1.775 0.8875 0.8875

4 Service connection to BPL No 554 166.2 387.8 56 56 0 150 75 75


ANNEXURE-X Contd…

Sl. No.


Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18

1 New Feeders/Lines

11KV Spur line for DTs Km 18.65 5.595 13.055 5.4 1.62 3.78 35.45 10.635 24.815


2.1 25 KVA No 11 4 7 2 1 1 13 4 9

2.2 63 KVA No 5 2 3 3 1 2 5 2 3

2.3 100 KVA No

Total MVA 0.59 0.239 0.64

3 LT Line Km 29.18 8.754 20.426 5.9 1.77 4.13 11.25 3.375 7.875

4 Service connection to BPL No 722 217 505 178 54 124 1299 400 899


ANNEXURE-X Contd…

Sl. No.

Item of Work Unit MON Yearwise Roll Out Plan ZHB Yearwise Roll Out Plan LGLG Yearwise Roll Out Plan

Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18

1 New Feeders/Lines

11KV Spur line for DTs Km 34.7 10.41 24.29 3.05 0.915 2.135


2.1 25 KVA No 8 3 5

2.2 63 KVA No 1 1 0 3 0.9 2.1

2.3 100 KVA No

Total MVA

0.263 0 0.189

3 LT Line Km 12.725 3.8175 8.9075 4.755 1.4265 3.3285

4 Service connection to BPL No 622 188 434 167 50.1 116.9


ANNEXURE-X Contd…

Sl. No.


Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18

1 New Feeders/Lines

11KV Spur line for DTs Km 49.75 14.92

5 34.825 4.9 1.47 3.43 166.25

50.175

116.075

0


2.1 25 KVA No 12 4 8 3 0.9 2.1 59 20.9 38.1 0

2.2 63 KVA No 3 1 2 23 8.9 14.1 0

2.3 100 KVA No 2 2 0 0

Total MVA

0.489 0.075 3.124 1.2832 1.8408 0

3 LT Line Km 13.225 3.9675 9.2575 1.4 0.42 0.98 96.41 29.278 67.132 0


No 760 228 532 235 70.5 164.5 4743 1504.8 3238.2 0


ANNEXURE-X YEARWISE PROPOSED INFRASTRUCTURE PLAN FOR ALREADY SANCTIONED NERPSIP DMS UNDER WORLD BANK FUNDING

Sl. No.


Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18 A. Feeder Separation

1 New 33KV Bay No 1 1.00 B. Strengthening of Sub-Transmission and Distribution Network

1 New 33/11 KV or 66/11 KV SS :

1.1 2x10 MVA, 33/11KV No 1 1.00

1.2 2x5 MVA, 33/11KV 1 1.00 1.00 1.00

1.3 2x2.5 MVA, 33/11KV 1 1.00 2 Augmentation of SS

2.1 2x 10 MVA, 33/11KV No 1 1 0.00

2.2 1x10 MVA, 33/11KV No 2 1 1.00

2.3 1x5MVA No 3 1 2.00 Total MVA 40 50 10

3 New Feeders/Lines

New 33KV Feeder Km 10 5 5.00 1 1 0.00 4.00 2 2.00

C. OPGW/ADSS

1 OPGW/ADSS Km 30 15 15.0 15 7.5 7.50 4.00 4.00


ANNEXURE-X Contd…

Sl. No.


Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY


1 New 33KV Bay No 2 2 0.00

B. Strengthening of Sub-Transmission and Distribution Network

1 New 33/11 KV or 66/11 KV SS :

1.1 2x10 MVA, 33/11KV No 1 1.00

1.2 2x5 MVA, 33/11KV 2 1 1.00

1.3 2x2.5 MVA, 33/11KV

2 Augmentation of SS

2.1 2x 10 MVA, 33/11KV No

2.2 1x10 MVA, 33/11KV No

2.3 1x5MVA No 2 1 1.00 2 1 1.00

Total MVA 10 50 0

3 New Feeders/Lines

New 33KV Feeder Km 30.5 12 18.50

C. OPGW/ADSS

1 OPGW/ADSS Km 80.5 40 40.50 67.00 67.00 0.00


ANNEXURE-X Contd…

Sl. No.

Item of Work Unit MON Year wise Roll Out Plan ZHB Year wise Roll Out Plan LGLG Year wise Roll Out Plan

Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY


1 New 33KV Bay No 4 2 2.00


1 New 33/11 KV or 66/11 KV SS :

1.1 2x10 MVA, 33/11KV No

1.2 2x5 MVA, 33/11KV 1 1.00 1 1.00 1.00 1.00

1.3 2x2.5 MVA, 33/11KV


2.1 2x 10 MVA, 33/11KV No

2.2 1x10 MVA, 33/11KV No

2.3 1x5MVA No 2 1 1.00

Total MVA 10 20 10

3 New Feeders/Lines

New 33KV Feeder Km 26 12 14.00 5.00 5 0.00 C. OPGW/ADSS

1 OPGW/ADSS Km 32 12 20.00 5.00 5 0.00


ANNEXURE-X Contd…

Sl. No.


Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY


1 New 33KV Bay No 7 0 4 3


1 New 33/11 KV or 66/11 KV SS :

1.1 2x10 MVA, 33/11KV No 2 0 0 2

1.2 2x5 MVA, 33/11KV 7 0 1 6

1.3 2x2.5 MVA, 33/11KV 1 0 0 1

2 Augmentation of SS 2.1 2x 10 MVA, 33/11KV No 1 0 1 0 2.2 1x10 MVA, 33/11KV No 2 0 1 1 2.3 1x5MVA No 9 0 4 5

Total MVA 0 0 200 0 60 140 3 New Feeders/Lines

New 33KV Feeder Km 76.5 0 37 39.5

C. OPGW/ADSS

1 OPGW/ADSS Km 233.5 0 146.5 87


ANNEXURE-X YEARWISE PROPOSED INFRASTRUCTURE PLAN FOR FUTURE IPDS SCHEME

Sl. No.


Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18 A. Strengthening of Sub-Transmission and Distribution Network

1 New 33/11 KV SS 1.1 2x10 MVA, 33/11KV No 2 1 1 0 1.2 1x10 MVA, 33/11 KV No 1 1 1.3 2x5 MVA, 33/11KV 1.4 1x5 MVA, 33/11KV No 1 1

2 Augmentation of SS 2.1 1x10 MVA, 33/11KV No 2 1 1 2.2 1x5MVA No 2.3 1x2.5 MVA No 2.4 1x1.6 MVA No

Total MVA 60 10 5


No. 4 2 2 1 1 0

4 New Feeders/Lines 4.1 New 33KV Feeder Km 9 4 5 4 4 0 20.00 20 0


Km 20 10 10 0

4.3 .New 11KV Feeder Km 50 30 20 4 4 0 1 1 0


Km 9 9 0

4.5 11KV Spur line for DTs Km 55.9 23 33 17 9 8 2.6 2.6 0


Sl. No.


Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18

5 Distribution Transformers 5.1 New DTs

5.1.1 100 KVA No 15

8 7 0

1

1 0

5.1.2 250 KVA No 78

30 48 24

8 16 2

2 0 5.2 Augmentation of DTR

5.2.1 100 KVA No.

0

1

1 0

5.2.2 250KVA. No. 16

8 8 1

1 0 2

2 0 5.2.3 500 KVA No. 34

15 19 6

3 3 0

Total MVA 42

9.25

1.2

6 LT Line Km 93.10

40.00 53.10 31.00

12.00 19.00 3.00

3.00 0.00

7 R&M of DTs Nos 93

40 53 0

B. Metering

1 SS & Feeder Nos 13

13 0 10

10 0 0

2 Distribution Transformer Nos 202

150 52 7

7 0

3 Consumer Nos 0

3.1 a). Prepaid meters Nos 18591

10000 8591 10300

6000 4300 0

3.2 b). 1Ph LT Electronic meters

16200

7000 9200 9000

5000 4000 1500

1000 500


10000

5000 5000 5000

3000 2000 100

100 0

Roof Top Solar Panel at SS Nos 9

6 3 3

1 2


ANNEXURE-X Contd…

Sl. No.

Item of Work Unit

WKH Year wise Roll Out Plan MKG Year wise Roll Out Plan TNSG Year wise Roll Out Plan

Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-

16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18

A. Strengthening of Sub-Transmission and Distribution Network 1 New 33/11 KV SS

1.1 2x10 MVA, 33/11KV No

1.2 1x10 MVA, 33/11 KV No

1.3 2x5 MVA, 33/11KV

1.4 1x5 MVA, 33/11KV No


2.1 1x10 MVA, 33/11KV No

2.2 1x5MVA No

1.00

1

2.3 1x2.5 MVA No

2.4 1x1.6 MVA No

Total MVA 0

0

5


No.

1

1 0

4 New Feeders/Lines

4.1 New 33KV Feeder Km


Km

4.3 New 11KV Feeder Km 1.5

1.5 0 1.2

1.2 0


Km

4.5 11KV Spur line for DTs Km 4.7

4.7 0 4.2

4.2 0 5

5 0


Sl. No.

Item of Work Unit

WKH Year wise Roll Out Plan MKG Year wise Roll Out Plan TNSG Year wise Roll Out Plan

Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-

16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18

5 Distribution Transformers

5.1 New DTs

5.1.1 100 KVA No 6

6 0 6

6 0 3

3 0 5.1.2 250 KVA No 0

0

2

2 0


5.2.1 100 KVA No. 0

0

5.2.2 250KVA. No. 3

3 0 2

2 0 0

5.2.3 500 KVA No. 0

1

1 0

Total MVA 1.35

1.6

0.8

6 LT Line Km 4.70

4.70 0.00 4.80

4.80 0.00 5.00

5.00 0.00 7 R&M of DTs Nos

B. Metering

1 SS & Feeder Nos 4

4 0 9

9 0 4

4 0


10

10 0 0

3 Consumer Nos

3.1 Prepaid meters Nos 0

0

0

3.2 1Ph LT Electronic meters 2000

1000 1000 1000

1000 0 3000

1500 1500 4 Relocation of inaccessible

meters 100

100 0 100

100 0 100

50 50

C. Roof Top Solar Panel at SS Nos 1

1 1

1 2

2


ANNEXURE-X Contd…

Sl. No.

Item of Work Unit MON Year wise Roll Out Plan ZHBT Year wise Roll Out Plan LGLG Year wise Roll Out Plan

Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

A. Strengthening of Sub-Transmission and Distribution Network

1 New 33/11 KV or 66/11 KV SS :

1.1 2x10 MVA, 33/11KV No 1.2 1x10 MVA, 33/11 KV No 1.3 2x5 MVA, 33/11KV 1.4 1x5 MVA, 33/11KV No 2 Augmentation of SS

2.1 1x10 MVA, 33/11KV No 2.2 1x5MVA No 2.3 1x2.5 MVA No 1 1 2.4 1x1.6 MVA No

Total MVA 2.5 0 0


No. 1 1 0

4 New Feeders/Lines 4.1 New 33KV Feeder Km


Km



Km


Sl. No.


Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18


2.75 0 2.5

2.5 0 3

3 0


5.1 New DTs

5.1.1 100 KVA No 3

3 0 3

3 0 3

3 0 5.1.2 250 KVA No 0

3

3 0 0


5.2.1 100 KVA No. 3

3 0

1

1 0

5.2.2 250KVA. No. 0

0

0

5.2.3 500 KVA No. 0

0

Total MVA 0.6

1.05

0.4

6 LT Line Km 7.85

7.85 0.00 2.00

2.00 0.00 6.00

6.00 0.00 7 R&M of DTs Nos

B. Metering

1 SS & Feeder Nos 5

5 0 10

10 0 9

9 0


0

17

17 0 3 Consumer Nos

3.1 Prepaid meters Nos 0

0

0

3.2 1Ph LT Electronic meters 1500

1000 500 2000

1000 1000 1630

800 830


100

100 0 100

50 50 100

50 50

C. Roof Top Solar Panel at SS Nos 1

1 1

1 1

1


ANNEXURE-X Contd…

Sl. No. Item of Work Unit PRN Year wise Roll Out Plan KPHR Year wise Roll Out Plan TOTAL Year wise Roll Out Plan

Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18 A. Strengthening of Sub-Transmission and Distribution Network

1 New 33/11 KV SS : 1.1 2x10 MVA, 33/11KV No 2 1 1 1.2 1x10 MVA, 33/11 KV No 1 0 1 1.3 2x5 MVA, 33/11KV 1.4 1x5 MVA, 33/11KV No 1 0 1 2 Augmentation of SS

2.1 1x10 MVA, 33/11KV No 2 1 1 2.2 1x5MVA No 1 0 1 2.3 1x2.5 MVA No 1 1 2 0 2 2.4 1x1.6 MVA No

Total MVA 2.5 0 85 0 30 55


No. 7 5 2

4 New Feeders/Lines 4.1 New 33KV Feeder Km 33.00 28.00 5


Km 20.00 10.00 10

4.3 New 11KV Feeder Km 57.70 37.70 20


Km 9.00 9.00 0



Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18

4.5 11KV Spur line for DTs Km 4 4 0 4 4 0 105.65 64.75 40.9


5.1 New DTs 5.1.1 100 KVA No 2 2 0 2 2 0 44 37 7 5.1.2 250 KVA No 2 2 0 2 2 0 113 49 64 5.2 Augmentation of DTR

5.2.1 100 KVA No. 5 5 0 5.2.2 250KVA. No. 0 0 24 16 8 5.2.3 500 KVA No. 41 19 22

Total MVA 0.7 0.7 59.65 0 29.95 29.7

6 LT Line Km 7.00 7.00 0.00 7.00 7.00 0.00 171.45 99.35 72.10 7 R&M of DTs Nos 93 40 53

B. Metering 1 SS & Feeder Nos 8 8 0 12 12 0 84 84 0 2 Distribution Transformer Nos 11 11 0 9 9 0 256 204 52 3 Consumer Nos

3.1 Prepaid meters Nos 0 0 28891 16000 12891 3.2 1Ph LT Electronic meters 900 500 400 1000 500 500 39730 20300 19430


50 50 0 50 50 0 15800 8650 7150

C. Roof Top Solar Panel at SS Nos 1 1 20 7 13


ANNEXURE-X YEARWISE PROPOSED INFRASTRUCTURE PLAN FOR FUTURE DDUGJY SCHEME

Sl. No. Item of Work Unit DMP Year wise Roll Out Plan KHM Year wise Roll Out Plan PHEK Year wise Roll Out Plan

Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18


2 New 11KV Bay No 2

2 0

3 New 33KV Line Kms.

4 New 11KV Line Kms. 35.00

15.00 20.00


1 New 33/11 KV or 66/11 KV SS :

1.1 1x2.5 MVA, 33/11KV No

1

1

1.2 1x 1.6MVA, 33/11KV No

1.3 1x 0.5 MVA, 33/11KV No


2.1 1x2.5 MVA No

2.2 1x1.6 MVA No

Total MVA 0

2.5

0

4 New Feeders/Lines


0.50

0.50 0.00


Km


3.00

3.00 0.00

3.4 Reconductoring of 11KV Km


Sl. No. Item of Work Unit DMP Year wise Roll Out Plan KHM Year wise Roll Out Plan PHEK Year wise Roll Out Plan

Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18 Feeder

3.5 33KV Spur Line for DTs Km


45.00 51.80 39.65

16.00 23.65 63.80

25.00 38.80


4.1 New DTs

4.1.1 25 KVA No 66

28 38 15

6 9 32

12 20 4.1.2 63 KVA No 21

9 12 15

6 9 20

8 12

4.1.3 100 KVA No 5

5 0

2


4.2.1 25KVA No.

4.2.2 63 KVA No.

4.2.3 250KVA. No.

Total MVA 3.473

1.32

2.26

5 LT Line Km 179.00

70.00 109.00 77.80

30.00 47.80 56.10

20.00 36.10

6 R&M of DTs Nos 71

30 41 77

35 42 45

20 25


No 8007

3500 4507 4091

1800 2291 6140

2500 3640

C. Metering


14 0 9

9 0 15

15 0 2 Distribution Transformer Nos 402

300 102 117

117 0 80

35 45

3 Consumer Nos

1Ph LT Electronic meters 22647

10000 12647 18994

8500 10494 19573

9500 10073


ANNEXURE-X

Contd…

Sl. No. Item of Work Unit WKH Year wise Roll Out Plan MKG Year wise Roll Out Plan TNSG Year wise Roll Out Plan

Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18


1.00

1 0

2 New 11KV Bay No


33.00

15.00 18.00 4 New 11KV Line Kms.


1 New 33/11 KV or 66/11 KV SS :

1.1 1x2.5 MVA, 33/11KV No 1

1

1.2 1x 1.6MVA, 33/11KV No

1

1 1

1 1.3 1x 0.5 MVA, 33/11KV No

1

1 0


2.1 1x2.5 MVA No

2.2 1x1.6 MVA No

2

1 1

Total MVA 2.5

4.8

2.1

4 New Feeders/Lines


10.00 10.00 10.00

10.00 0.00 25.50

11.50 14.00


Km


1.50 0.00 3.00

3.00 10.50

5.00 5.50 3.4 Reconductoring of 11KV Km


Sl. No. Item of Work Unit WKH Year wise Roll Out Plan MKG Year wise Roll Out Plan TNSG Year wise Roll Out Plan

Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18 Feeder



12.00 14.50 43.15

18.00 25.15 42.15

17.00 25.15


4.1 New DTs

4.1.1 25 KVA No 20

9 11 26

10 16 26

12 14 4.1.2 63 KVA No 7

3 4 10

4 6 21

7 14

4.1.3 100 KVA No

2

2 0 1


4.2.1 25KVA No.

2

2 0

4.2.2 63 KVA No.

6

6 0 4.2.3 250KVA. No.

Total MVA 0.941

1.48

2.501

5 LT Line Km 35.80

15.00 20.80 46.70

20.00 26.70 27.70

12.00 15.70

6 R&M of DTs Nos 26

10 16 69

30 39 35

15 20


No 3993

1500 2493 5621

2000 3621 7751

3500 4251

C. Metering


25 0 37

20 17 32

15 17 2 Distribution Transformer Nos 136

65 71 141

65 76 229

100 129

3 Consumer Nos


7500 8316 19401

9500 9901 14389

7000 7389


ANNEXURE-X Contd…

Sl. No.


Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18


2 New 11KV Bay No




1 New 33/11 KV or 66/11 KV SS :

1.1 1x2.5 MVA, 33/11KV No 1

1 2

1 1

1.2 1x 1.6MVA, 33/11KV No

1.3 1x 0.5 MVA, 33/11KV No


2.1 1x2.5 MVA No 1

1 0

2.2 1x1.6 MVA No

Total MVA 5

5

0

4 New Feeders/Lines


10.00 8.00 17.00

8.00 9.00


Km


4.00 2.00 10.50

5.00 5.50


Km


Sl. No.


Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18



30.00 45.30 95.25

40.00 55.25 17.30

8.00 9.30 4 Distribution Transformers

4.1 New DTs

4.1.1 25 KVA No 62

28 34 79

32 47 23

9 14

4.1.2 63 KVA No 13

6 7 34

14 20

4.1.3 100 KVA No 1

1 0


4.2.1 25KVA No.

4.2.2 63 KVA No.

1

1 0

4.2.3 250KVA. No.

Total MVA 2.469

4.18

0.575

5 LT Line Km 63.80

29.00 34.80 95.00

45.00 50.00 24.99

10.00 14.99 6 R&M of DTs Nos 44

20 24 43

20 23 20

10 10

7 Service connection to BPL No 6934

3000 3934 6815

3000 3815 1744

750 994 C. Metering


10 9 15

8 7 9

4 5


120 144 272

130 142 100

40 60 3 Consumer Nos


9000 9866 8232

4000 4232 5345

2500 2845


ANNEXURE-X Contd…


Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18

A. Feeder Separation

1 New 33KV Bay No

1

1 0 2 New 11KV Bay No

2

2 0


33.00

15.00 18.00 4 New 11KV Line Kms. 26.00

10.00 16.00

61.00

25.00 36.00


1 New 33/11 KV or 66/11 KV SS :

1.1 1x2.5 MVA, 33/11KV No 1

1

6

1 5 1.2 1x 1.6MVA, 33/11KV No

2

0 2

1.3 1x 0.5 MVA, 33/11KV No

1

1 0 2 Augmentation of SS

2.1 1x2.5 MVA No

1

1 2

1 1

2.2 1x1.6 MVA No

2

1 1 Total MVA 2.5

2.5

26.9 0 7.1 19.8

3 New Feeders/Lines


10.00 15.00

116.00

60.00 56.00


Km


4.50 0.00

39.00

23.00 16.00


Km



Qty FY

2015-16 FY

2016-17 FY

2017-18 Qty

FY 2015-16

FY 2016-17

FY 2017-18

Qty FY

2015-16 FY

2016-17 FY

2017-18



30.00 45.10 23.50

10.00 13.50 598.50

251.00 347.50 4 Distribution Transformers

4.1 New DTs

4.1.1 25 KVA No 37

15 22 13

5 8 399

166 233

4.1.2 63 KVA No 5

5 0 16

8 8 162

70 92 4.1.3 100 KVA No

3

3 0 14

14 0


4.2.1 25KVA No. 1

1 0

3

3 0 4.2.2 63 KVA No. 1

1 0

8

8 0

4.2.3 250KVA. No.

1

1 0 1

1 0 Total MVA 1.328

1.883

22.41 0 10.789 11.621

5 LT Line Km 54.60

24.00 30.60 23.06

9.00 14.06 684.55

284.00 400.55 6 R&M of DTs Nos 16

8 8 27

12 15 473

210 263

7 Service connection to BPL No 3916

1700 2216 1548

700 848 56560

23950 32610 C. Metering

1 SS & Feeder Nos 8

8 0 8

5 3 191

133 58


40 49 136

60 76 1966

1072 894 3 Consumer Nos


2000 2246 4114

2000 2114 151623

71500 80123


ANNEXURE-XI

Details of System Strengthening Plan of Nagaland FY 2015-16 to 2017-18

Category Schemes involved Benefits Basis/Norms Load Growth Creation of new

substations and associated 33/11kV Lines

• To meet with the load growth in the area

• To release new connection of various categories

• Reduction in the loading on the existing Sub-Stations.

• Reduction of the AT&C losses of the overloaded system.

• The Existing loading of the sub-station is analysed.

• The Load growth of the sub-station is calculated taking into consideration:

a) Load growth on the basis of peak load recorded on AP and other feeders in previous two years to facilitate running of AP feeders in two groups

b) To ensure Reliable power supply to other categories based on load projections.

• On the basis of load growth worked out and present loading condition of the Sub-Station, Augmentation of existing Sub-Station is proposed if technically feasible other wise creation of new sub-station is proposed near load centre.

Augmentation of existing substations and associated 33kV Lines



• Reduction in the loading on the existing Sub-Stations.

• Reduction of the AT&C losses of the overloaded system.

• The Existing loading of the sub-station is analysed.

• The Load growth of the sub-station is calculated taking into consideration:

a) Load growth on the basis of peak load recorded on AP and other feeders in previous two years to facilitate running of AP feeders in two groups

b) To ensure Reliable power supply to other categories based on load projections.

• On the basis of load growth worked out and present loading condition of the Sub-Station, Augmentation of existing Sub-Station is proposed if technically feasible.


Category Schemes involved Benefits Basis/Norms Load Growth Bifurcation /

trifurcation of 11kV feeders

• To achieve voltage regulation at tail end.

• Reduction in Technical losses due to decrease in length of 11 KV overloaded lines and appropriate size of conductor.

• Reduction in tripping resulting into increase in reliability of power / consumer satisfaction.

• The Voltage of feeder at tail end is analyzed.

• If the loading of the feeder goes beyond 200 Amps, bifurcation/trifurcation of the feeder is proposed.

Augmentation of Existing DT and associated LT line



• Reduction in the loading on the existing Distribution Transformer.

• To achieve Steady & desired voltage level.

• Based on the peak load recorded on the existing DTs and the new connections applied in the area.

• On the basis of the present loading of the Distribution Transformer, existing DT is augmented if feasible else new DT is proposed.

Providing Additional Distribution Transformer and associated 11kV and LT Line



• Reduction in the loading on the existing Distribution Transformer.

• To achieve Steady & desired voltage level.

• Based on the peak load recorded on the existing DTs and the new connections applied in the area.

• On the basis of the present loading of the Distribution Transformer, A new DT is proposed if the existing DT cannot be augmented.

AT&C loss reduction

AMR, CMRI and replacement of defective and electromechanical meters

• Accurate meter reading from remote locations.

• Minimization of human intervention in meter reading.

• Timely generation of bills

• No blockage of Revenue on account of defective meters

Meter Reading Technology has been finalized as below : • HT Consumers above 50KW: AMR

already Provided. • LT consumers between 20KW-

50KW : AMR • DS/NDS/LT Consumers Below

20KW: CMRI/PDS. • Through CMRI all data including

energy consumption i.e units consumed takes minimum 7-8 mins. By using PDS only meter reading i.e units consumed can be downloaded


Category Schemes involved Benefits Basis/Norms which shall take less than a minute per consumer. However, in suspicious cases all data can be downloaded through CMRI.

• Prepaid metering / smart metering for Govt. Institutions.

AT&C loss reduction

Shifting of meters outside the consumer’s premises and at reasonable height for proper reading

• Effective curbing of pilferage of energy by unauthorized consumers.

• Accurate recording of energy consumption.

• Avoidance of meter tampering

• In urban & Semi-urban areas meters are to be shifted outside the consumer premises and installed at outer wall (preferably) or nearby pole.

• In rural areas, the meters shall be shifted outside consumer premises in meter boxes such as 1-in-1, 2-in-1, 4-in-1 & 6-in1 and in extreme cases 20-in-1 meter pillar boxes.

• LT conductor would also be replaced with AB cable in theft prone areas.

Replacement of Bare Conductor by LT AB Cable in theft prone areas

• To mitigate direct hooking on the LT System.

Only in theft prone and rural areas.

Replacement of Undersized Conductors / outlived or worn out Conductors on feeders with frequent breakdowns

• Reduction in Technical losses due to replacement by appropriate size of conductor.

• Reduction in tripping resulting into increase in reliability of power/consumer satisfaction.

• Provision of 80 – 100 Sqmm conductor in City areas

• Existing conductors can be changed as per the requirements in phases


ANNEXURE-XII

Power Purchase cost projected by DOPN for FY 2015-16

Sl. No. Source 2015-16 (Projected)

Purchase (MU) Rate (Rs./ KWh) Total

Cost Rs. Crore I NEEPCO 1 Khandong, 11.00 3.17 3.49

2 Kopili-I 40.00 1.17 4.68

3 Kopili-II, 3.03 2.16 0.65 4 Ranganadi, 60.00 3.97 23.82 5 AGTPP, Tripura 30.00 4.49 13.48

6 AGBPP, Kathalguri 95.00 4.16 39.56

7 Doyang, Nagaland 18.00 5.02 9.03

II NHPC

1 Loktak, Manipur 32.00 2.81 8.98 III NTPC 120.00 4.04 48.50

IV OTPC Ltd. - Palatana 84.93 3.06 25.96

V Short Term - GEFL Ltd 7.09 3.73 2.65 VI Short Term - NVVNL Ltd 12.99 3.86 5.01

VII Short Term - PTC Ltd 33.43 4.06 13.56

VIII Over drawn /other sources 52.64 3.90 20.51

IX PGCIL (Trans.Chrges) 600.11 0.46 27.33

X NERLDC/NERPC Charges 1.10

XI Total Energy Purchase 600.11 4.14 248.31

XII Free Power from Doyang 27.00 0 0

XIII (Total energy available) 627.11 3.96 248.31

XIV Arrear energy bill/IT/others 4.93

XV Total of the year 627.11 253.24

Source: - Tariff order for FY 2015-16


ANNEXURE-XIII

AVERAGE BILLING RATE

Sl.no Description Rate (Rs/unit)

FY 2015-16 FY 2016-17 FY 2017-18 FY 2018-19

MU Rs Crores MU Rs Crores MU Rs Crores MU Rs Crores

1 Domestic 4.28 399.42 171 537.82 230 703.01 301 854.5 365 2 Other than

domestic 5.75 79.15 46 99.56 57 125.24 72 157.54 91

Total 478.57 217 637.38 287 828.25 373 1012.04 456

Weighted average ABR

Rs/unit 4.53

4.50

4.50

4.51

LEGEND220 kV sub-station132 kV sub-station66 kV sub-station 132 kV line of Nagaland66 kV line of Nagaland220 kV line of PGCIL132 kV line of Manipur132 kV line of Assam

HEP

KarongManipur

220 kV PGCIL from Misa S/S (Assam)

24 MW Likimro HEP

132/66 kV KiphireS/S

66/33 kV Tuensang S/S

132/66/33 kV Mokokchung S/S

132/33 kV Wokha S/S

75 MW Doyang HEP

220/132 kV PGCIL S/S

132/66/33 kV Nagarjan S/S

132/33 kV Kohima S/S

66/33 kV Zunheboto S/S

132/33 kV Meluri S/S

66/33 kV Tuli S/S

66/33 kV Naganimora S/S

66/33 kV Tizit S/S

66/33 kV Mon S/S

66/33 kVChumukedima S/S

220/132 kV Mariani S/S

POWER MAP OF NAGALAND: 66 kV AND ABOVE

Department of PowerNagaland: Kohima

66/33 kV Ganeshnagar S/S

Mao

66/33 kV SSPurana bazaar, Burma camp, Nito farm

a joint initiative of government of india and government...

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