Filed by Dakshin Haryana Bijli Vitran Nigam Limited Hisar FY...and Annual Revenue Requirement for FY 2018-19 by Dakshin Haryana Bijli Vitaran Nigam Limited under HERC (Terms and Conditions

BEFORE

HARYANA ELECTRICITY REGULATORY COMMISSION

Filing of the Petition for True-Up of FY 2016-17, Annual Performance review for FY 2017-18

and Annual Revenue Requirement for FY 2018-19 by Dakshin Haryana Bijli Vitaran Nigam

Limited under HERC (Terms and Conditions for Determination of Tariff for Distribution &

Retail Supply under Multi Year Tariff Framework) Regulations, 2012 along with the other

guidelines and directives issued by the Hon’ble Commission from time to time and under

Sections 42, 45, 46, 47, 61, 62, 64 and 86 of the Electricity Act 2003 read with the relevant

guidelines.

Filed by

Dakshin Haryana Bijli Vitran Nigam Limited

Hisar

Superintending Engineer/Regulatory Affairs Regd. Office: C-Block, Vidyut Sadan, Vidyut Nagar, Hisar-125005, Haryana (India)

Email [email protected] Phone 01662-223196

Date: 30 November 2017

mailto:[email protected]

ii

Petition for True up of FY 2016-17, APR FY 2017-18 and ARR for FY 2018-19 DHBVNL

DAKSHIN HARYANA BIJLI VITRAN NIGAM LIMITED (A Power Distribution & Retail supply Utility, Govt. of Haryana)

Regd. Office: C-Block, Vidyut Sadan, Vidyut Nagar, Hisar-125005, Haryana (India) Phone 0172-2568824 E-mail [email protected] Web Site: www.dhbvn.com

BEFORE THE HARYANA ELECTRICITY REGULATORY COMMISSION,

PANCHKULA

IN THE MATTER OF: Filing of the Petition for True-up of FY 2016-17, Annual

Performance Review (APR) for FY 2017-18, Annual Revenue

Requirement (ARR) for FY 2018-19 by Dakshin Haryana Bijli

Vitran Nigam Ltd. under HERC (Terms and Conditions for

determination of tariff for generation, transmission, wheeling

and distribution & retail Supply under Multi Year Tariff

Framework) Regulations, 2012 and under Section 45, 46, 47,

61, 62, 64 and 86 of The Electricity Act 2003 read with the

relevant guidelines.

AND

IN THE MATTER OF: DAKSHIN HARYANA BIJLI VITRAN NIGAM LIMITED

(hereinafter referred to as "DHBVN”), having its registered

office at Vidyut Sadan, Panchkula, Haryana.

DHBVN (hereinafter Petitioner) respectfully submits as under: -

The Petitioner is a State owned Distribution Company and registered under the

companies Act, 1956, formed under corporatisation/ restructuring of erstwhile

Haryana State Electricity Board (HSEB) and is credit worthy for the distribution and

retail supply of electricity (License No. DRS-1 of 2004) in the South Zone of State

Haryana.

Pursuant to the enactment of the Electricity Act, 2003, every utility is required to

submit its Annual Revenue Requirement (ARR) for the control period and Tariff

Petitions as per procedures outlined in section 61, 62 and 64 of Electricity Act 2003,

and the HERC (Terms and conditions for Determination of Tariff for Distribution &

Retail Supply under Multi Year Tariff Framework) Regulations, 2012 as amended

from time to time.

The Annual Revenue Requirement (ARR) petition for FY 2016-17along with True-up

for FY 2014-15 was filed by DAKSHIN HARYANA BIJLI VITRAN NIGAM LIMITED

(hereinafter referred to as "DHBVN”) and accordingly the Hon’ble Commission had

issued the Tariff Order against the said petition on 1st August, 2016.

http://www.dhbvn.com/

iii


1. The present petition is being filed with the Hon’ble Commission for True-up of FY

2016-17, Annual Performance Review (APR) for FY 2017-18 and Annual Revenue

Requirement (ARR) for FY 2018-19.

2. This petition has been prepared in accordance with the provisions of Part VII-

Principles for Determination of Tariff and Norms of Operation for Distribution

Businessand Part VIII -Filing Of Aggregate Revenue requirement, as per the HERC

(Terms and Conditions for Determination of Tariff for Generation, Transmission,

Wheeling and Distribution & Retail Supply under Multi Year Tariff Framework)

Regulations, 2012 along with Sections 61, 62 of the Electricity Act, 2003,

3. The present petition is being filed before the Hon’ble Commission for True-up of

FY 2016-17, Annual Performance Review (APR) for FY 2017-18 and Annual

Revenue Requirement (ARR and Tariff for FY 2018-19) considering the approved

values of HERC Tariff Order dated 1st August, 2016 and subsequent HERC tariff

order 11th July, 2017 .

4. DHBVN along with this petition is submitting the regulatory formats with data &

information to an extent applicable and would make available any further

information/ additional data required by the Hon’ble Commission during the

course of proceedings.

5. The current APR being filed has been discussed and being approved by the BODs

of the DHBVN and Sh. Rajender Sabarwal, SE/Regulatory Affairs, DHBVN has

been authorized to execute and file the said APR on behalf of DHBVN.

6. The Hon’ble Commission has not extended the purview of Multi Year Tariff

Regulation, 2012 to the FY 2018-19. Therefore, the Licensee in absence of any

Regulation has determined the ARR of FY 2018-19 as per the current Multi Year

Tariff Regulation, 2012. Also, the True-up of FY 2016-17 has been done as per the

aforementioned regulations.

7. However, DHBVN is filing a petition before the Hon’ble Commission while

reserving its right to file any additional submissions and revised petition

iv


Prayers to the Commission:

The petitioner respectfully prays that the Hon’ble Commission may:

• Take the accompanying filing of DHBVN on record and accept the petition

regarding true up of expenses and revenue for FY 2016-17, Re-estimation of

Revenue Requirement / Gap for FY 2017-18 and projected Revenue

Requirement for FY 2018-19;

• Allow filing of any additional / supplementary submissions during the course

of these proceedings;

• Allow return on equity as proposed;

• Allow the entire fixed charges of power purchase as the power is procured from

the sources whose PPAs have been duly approved by the Hon’ble Commission

and also the energy charges of power procurement from these sources as

proposed in the filing;

• Allow the Annual Revenue Requirement of the Nigam for the FY 2018-19

including the actual interest on all the loans which is real expenditure borne by

the utility;

• Allow True-Up of FY 2016-17 along with the holding cost and the revised

expenses as projected for FY 2017-18 in the Annual Revenue Requirement of FY

2018-19;

• To continue the current levels of Tariff to meet the expenses, the gap being

funded through operational financing as proposed under UDAY scheme;

• To allow Additional Surcharge of Rs 1.21 per unit to be recovered from Open

Access Consumers

• Condone any inadvertent omissions/errors/shortcomings and permit

DHBVN to add/change/modify/alter this filing and make further

submissions as may be required during the course of these proceedings;

v


• Pass such Order, as the Hon’ble Commission may deem fit and appropriate

keeping in view the facts and circumstances of the case submitted by the

Petitioner.

Panchkula, Haryana

Dated:

Dakshin Haryana Bijli Vitran

Nigam Limited

Petitioner

vi


Table of Contents

CHAPTER 1. INTRODUCTION ........................................................................................ 1

1.1 BACKGROUND – INDIAN POWER SECTOR ......................................................................... 1 1.2 ALL INDIA INSTALLED CAPACITY ...................................................................................... 2 1.3 PROFILE OF DHBVNL ....................................................................................................... 4 1.4 TRANSMISSION & DISTRIBUTION LOSSES ......................................................................... 7 1.5 REVENUE ............................................................................................................................ 9 1.6 HT-LT RATIO .................................................................................................................... 9 1.7 REGULATORY FRAMEWORK ............................................................................................. 10 1.8 CURRENT PETITION .......................................................................................................... 12

CHAPTER 2. TRUE-UP OF FY 2016-17 .......................................................................... 14

2.1 PRINCIPLES OF TRUE UP FOR FY 2016-17 ......................................................................... 14 2.2 POWER PURCHASE AND POWER PURCHASE COST ........................................................... 15 2.3 ENERGY BALANCE ............................................................................................................ 20 2.4 OPERATION & MAINTENANCE EXPENSES ........................................................................ 21 2.5 EMPLOYEE EXPENSES ....................................................................................................... 22 2.6 REPAIR & MAINTENANCE EXPENSES ............................................................................... 23 2.7 ADMINISTRATIVE & GENERAL EXPENSES ........................................................................ 24 2.8 CAPITAL EXPENDITURE .................................................................................................... 24 2.9 INTEREST COST ON LONG TERM LOANS........................................................................... 24 2.10 INTEREST ON WORKING CAPITAL AND BORROWINGS .................................................... 25 2.11 INTEREST ON CONSUMER SECURITY DEPOSITS ............................................................... 25 2.12 INTEREST ON BONDS ....................................................................................................... 25 2.13 TOTAL INTEREST & FINANCE COST ................................................................................. 26 2.14 DEPRECIATION ................................................................................................................. 27 2.15 RETURN ON EQUITY ......................................................................................................... 27 2.16 NON – TARIFF INCOME .................................................................................................... 28 2.17 EXPENDITURE DUE TO OTHER DEBTS ............................................................................... 28 2.18 TRUE UP OF RE SUBSIDY .................................................................................................. 29 2.19 SUMMARY OF TRUE UP OF FY 2016-17 .............................................................................. 29

CHAPTER 3. ANNUAL PERFORMANCE REVIEW FOR FY 2017-18 AND ANNUAL REVENUE REQUIREMENT FOR FY 2018-19 ............................................... 32

3.1 PREAMBLE ........................................................................................................................ 32 3.2 CAPITAL EXPENDITURE .................................................................................................... 32 3.3 TRANSMISSION AND DISTRIBUTION LOSSES. ................................................................. 35 3.4 CAPITAL WORK IN PROGRESS ......................................................................................... 35 3.5 ASSESSMENT OF ENERGY SALES FOR 2017-18 AND 2018-19 ............................................. 36 3.6 ENERGY AVAILABILITY FOR HARYANA FOR FY 2017-18 AND FY 2018-19 ........................ 37 3.7 TRANSMISSION LOSSES ................................................................................................... 46 3.8 ENERGY BALANCE – DHBVNL ........................................................................................ 46 3.9 OPERATION & MAINTENANCE EXPENSES ........................................................................ 48 3.10 COMPUTATION OF INFLATIONARY INDICES .................................................................... 50 3.11 EMPLOYEE EXPENSES ....................................................................................................... 51 3.12 REPAIR & MAINTENANCE EXPANSES ............................................................................... 52 3.13 ADMINISTRATION & GENERAL EXPENSES ....................................................................... 53 3.14 SUMMARY OF O&M EXPANSES ....................................................................................... 54 3.15 INTEREST & FINANCE CHARGES ...................................................................................... 54

vii


3.16 DEPRECIATION ................................................................................................................. 64 3.17 NON-TARIFF INCOME ...................................................................................................... 66 3.18 RETURN ON EQUITY ......................................................................................................... 67 3.19 INTEREST ON CONSUMER SECURITY DEPOSIT ................................................................. 67 3.20 BAD AND DOUBTFUL DEBTS ............................................................................................ 68 3.21 REVENUE ESTIMATION .................................................................................................... 68 3.22 REVENUE FROM INTER-STATE SALES: ............................................................................... 69 3.23 REVENUE FROM FSA: ............................................................... ERROR! BOOKMARK NOT DEFINED. 3.24 AGRICULTURE SUBSIDIES: ............................................................................................... 69 3.25 TARIFF REQUIREMENT: .................................................................................................... 69 3.26 TRUE UP OF RE SUBSIDY FOR FY 2016-17 ......................................................................... 72

CHAPTER 4. RECOVERY OF OUTSTANDING GAPS ............................................... 74

CHAPTER 5. ADDITIONAL SURCHARGE .................................................................. 75

CHAPTER 6. COMPLIANCE TO DIRECTIVES ISSUED IN LAST TARIFF ORDER 81

CHAPTER 7. PRAYER ..................................................................................................... 102

viii


List of Tables

Table 1: Details of division and sub-division offices ............................................................................................... 5

Table 2: Category wise Sales (MUs) for last six years ........................................................................................... 5

Table 3: Power Purchase Details for FY2016-17 .................................................................................................. 16

Table 4: Power Purchase Details for FY-2016-17 for Haryana (in MU) ............................................................. 20

Table 5: Energy Balance for FY 2016-17 .............................................................................................................. 20

Table 6: O&M Expenses for FY 2016-17 (Rs. Crore) .......................................................................................... 22

Table 7: Employee Expenses for FY 2016-17 (Amt. in Rs. Crore) ....................................................................... 22

Table 8: R&M Expenses for FY 2016-17 (Amount in Rs. Crore) ........................................................................ 23

Table 9: A&G Expenses for FY 2016-17 (Rs. Crore) ........................................................................................... 24

Table 10: Total Interest & Finance Cost for FY 2016-17 (Rs. Crore.) ................................................................. 26

Table 11: True up of RE subsidy for FY 2016-17 ................................................................................................. 29

Table 12: True Up of Expenses for FY 2016-17 (Rs. Crore) ................................................................................. 30

Table 13: Final True up of FY 2016-17 in Rs Cr. ................................................................................................ 31

Table 14: Summary of funding of capital expenditure in FY 2017-18 and 2018-19 ............................................ 32

Table 15: Scheme Wise details for the FY 2018-19 ............................................................................................... 33

Table 16: Summary of CWIP (Rs. Crore) ............................................................................................................. 35

Table 17: Statement of sales for FY 2017-18 and FY 2018-19 (Mus) .................................................................. 37

Table 18: Power Purchase Quantum Availability and Costs – Projected for FY 2017-18 and FY 2018-19 ........ 40

Table 19: Summary of Power Purchase in Rs Cr. ................................................................................................ 46

Table 20: Energy Balance for DHBVN ................................................................................................................ 47

Table 21: Bulk Supply Tariff for DHBVN ........................................................................................................... 47

Table 22: Inflation factor for WPI & CPI ............................................................................................................. 51

Table 23: Employee Expenses for FY 2018 and FY 2018-19 (Amt. in Rs. Crores) .............................................. 52

Table 24: R&M Expenses for FY 2018 and FY 2018-19 (Amt. in Rs. Crores) .................................................... 53

Table 25: A&G Expenses for FY 2018 and FY 2018-19 (Amt. in Rs. Crores) ..................................................... 54

Table 26: Summary of O&M Expenses for FY 2018 and FY 2018-19 (Amt. in Rs. Crores) ............................... 54

Table 27: Loan Profile and interest Liability of the Nigam for FY 2017-18 (Amount in Crores) ........................ 60

Table 28: Loan Profile and Interest Liabilities of the Nigam for FY 2018-19 (Amount in Crores) ...................... 62

Table 29: Net Interest & Finance Charges (Amount in Crores) .............................. Error! Bookmark not defined.

Table 30: Asset wise Depreciation rate ................................................................................................................. 64

Table 31: Depreciation for FY 2017–18 (Amount in Crores) ............................................................................... 65

Table 32: Depreciation for FY 2018-19 (Amount in Crores) ............................................................................... 65

Table 33: Non-Tariff income for FY 2018 and FY 2018-19 (Amt. in Rs. Crores) ............................................... 66

Table 34: Return on Equity for FY 2018 and FY 2018-19 (Amt. in Rs. Crores) ................................................. 67

Table 35: Interest on Consumer Security Deposit for FY18 & FY19 (Amt. in Rs Crores) .................................. 67

Table 36: Revenue Estimations for FY 2017-18 and FY 2018-19 (In Crs.) ......................................................... 69

Table 37: Aggregate Revenue Requirement for FY 2017-18 and FY 2018-19 (Amt. in Rs Crores) .................... 70

Table 38: Aggregate Revenue Requirement of Wheeling and Retail Supply (Amount in Rs. Crores) ................ 72

Table 39: True up of RE subsidy for FY 2016-17 ................................................................................................. 73

Table 40: Approved Per unit fixed cost of power purchase for FY 2017-18 ......................................................... 77

Table 41: Details of backing down owing to Open Access and Open Access units.............................................. 79

Table 42: Calculation of Additional Surcharge for Second half of FY 2016-17. ................................................... 80

ix


Page 1


Chapter 1. Introduction

1.1 Background – Indian Power Sector

The Indian power sector has witnessed versatile changes over the last decade

post the passage of The Electricity Act, 2003. These changes include

introduction of significant reform measures, enhanced regulatory regime,

increased level of private sector participation, development of state-of-the-

art grid linking the entire country and focus on renewable energy generation.

Energy requirement and supply is a strategic input and one of the key

drivers for economic and social development behind any growing country.

As energy plays a very vital role in industrial production, economic growth

and common man’s life, it has become extremely essential to boost the

growth in energy segment for the growth of the Country.

With growing demand in the energy requirement, the annual per capita

energy consumption has grown significantly. However the low per capita

consumption in the Country as compared to the world average indicates

significant potential for sustainable growth in the demand of electricity.

All INDIA PER CAPITA CONSUMPTION (IN KWH)

631.4 671.9 717.1 733.5 778.6 818.8883.63 914.41 957 1010

1075 1122

0

200

400

600

800

1000

1200

1400

2005-06 2006-07 2007-08 2008-09 2009-10 2010-11 2011-12 2012-13 2013-14 2014-15 2015-16 2016-17

P E R C A P I T A C O N S U M P T I O N

Page 2


Distribution is the most critical segment of electricity business chain. The

distribution segment is still largely government owned and will require

sustained attention of the authorities if the sector performance is to improve.

The real challenge of reforms in the power sector lies in efficient

management of the distribution sector. It is therefore necessary to improve

the distribution infrastructure and the management of distribution utilities.

1.2 All India Installed Capacity

India is one of the largest power-generating countries in the world with an

installed capacity of 3, 26,832 MW (as of March, 2017). Over the last 11years,

the installed capacity of the country has grown at a CAGR of 8.57%.

All India Installed Capacity (In Mw) – As On March 2017

Similarly, the electricity generation increased from about 5.1 Billion units in

1950 to 1,153.5 BU (including imports) in the year 2016-17 (till Jan-2017). The

Page 3


per capita consumption of electricity in the country has also increased from

15 kWh in 1950 to about 1,122 kWh in the year 2016-17. Out of 597464 census

villages, 5, 95,160 villages (99.6%) have been electrified as on 31.10.2017.

Regional grids have been integrated into a single national grid with effect

from 31.12.2012 thereby providing free flow of power from one corner of the

country to another through strong inter regional AC and HVDC links. As a

result, the All India peak demand (MW) as well as energy (MU) shortage

have registered steady decline. The peak shortage and energy shortage were

1.63% and .66% respectively during FY 2016-17.

India Fuel Wise Share In Installed Generation Capacity (MW) – As on Mar’17

All India Peak and Energy Deficit March 2017

35%

5%0%40%

1%8%

11%

Fuel Wise Share in installed Generation

Coal Gas Diesel Thermal Nuclear Hydro Res

10.10%

8.50% 8.50% 8.70%

4.20%3.60%

2.11% 0.66%

12.70%

9.80%10.60%

9.00%

4.50% 4.70%

3.20%

1.63%

0.00%

2.00%

4.00%

6.00%

8.00%

10.00%

12.00%

14.00%

FY 10 FY 11 FY 12 FY 13 FY 14 FY 15 FY 16 FY 17

Energy Deficit Peak Deficit

Page 4


1.3 Profile of DHBVNL

The Company is a Distribution Licensee within the meaning of Section 2 (17)

of Electricity Act 2003 and pursuant to the Section 14 of the Electricity Act.

Further, Section 42 and 43 of the Electricity Act 2003 prescribes the following

duties of the Distribution Licensee:

• To develop and maintain an efficient, co-ordinated and economical

distribution system;

• To supply electricity on an application of the consumer in accordance

with the provisions specified in the Electricity Act 2003;

• To provide non-discriminatory open access to the consumers;

• To establish a forum for redressal of grievances of the consumers;

Since DHBVN has been vested with the function of distributing power

by the State Government of Haryana, the Business Scope of the

Company falls within the legal framework as specified in the Act and

can include:

• To develop and maintain an efficient, co-ordinated and economical

distribution system;

• To Operate the existing distribution infrastructure efficiently &

effectively;

• Merchant Sale of Power in the event of availability of surplus power after

meeting the requirement of own consumers with whom the capacity is

contracted presently;

Page 5


• Other associated business like providing Training, Research and

Development activities, Technical consultancy services and O&M

related services;

• Contracts for outsourcing of distribution related activities, joint venture

participation;

Table 1: Details of division and sub-division offices

Name of Circle Total No. of Division Total No. of Sub-Division

Sirsa 3 13

Hisar 3 13

Bhiwani 3 17

Rewari 3 9

Gurgaon-I 2 8

Gurgaon-II 2 7

Palwal 2 11

Faridabad 4 18

Narnual 2 8

Jind 3 12

Fatehabad 2 11

DHBVN 29 127

The following table shows the total sales from FY 2011-12 to FY 2016-17 as

per actual audited accounts:

Table 2: Category wise Sales (MUs) for last six years

Category FY 2011-12 FY 2012-13 FY 2013-14 FY 2014-15 FY 2015-16 FY 2016-17

Domestic 2,920.44 3,059.32 3,671.97 3,899.42 4,152.52 4,589.16

Non-Domestic 1,929.60 1,837.26 1,864.03 2,161.04 2,402.07 2,548.65

HT Industry 3,794.47 3,895.79 4,563.45 5,053.43 4,723.18 4,521.60

Lift Irrigation 157.03 145.61 156.06 152.15 157.55 148.29

LT Industry 652.10 645.27 780.46 819.72 878.56 898.95

Agriculture 3,332.55 3,647.30 4,398.93 5,072.62 5,196.80 5,614.52

Bulk Supply 339.36 496.20 773.64 670.18 555.53 676.60

Railway Traction 159.28 159.92 157.38 160.23 169.88 197.45

Street Lighting 44.28 42.46 57.48 56.01 63.45 91.79

Page 6


Category FY 2011-12 FY 2012-13 FY 2013-14 FY 2014-15 FY 2015-16 FY 2016-17

Public Water Work 328.69 342.91 414.93 451.25 477.68 524.91

Total 13,657.80 14,272.03 16,838.32 18,496.05 18,777.21 19,811.92

CATEGORY-WISE SALES MIX – YEAR-WISE

As seen from the above figure Domestic category and Agriculture

consumption although varying but remains the highest (51.50% in FY17)

consuming category followed by HT Industrial at 22.82%. The HT Industrial

and LT Industrial contribute for more than 27.36% of the total consumption.

-

5,000.00

10,000.00

15,000.00

20,000.00

FY 2011-12 FY 2012-13 FY 2013-14 FY 2014-15 FY 2015-16 FY 2016-17

Domestic Non Domestic HT Industry Lift Irrigation LT Industry

Agriculture Bulk Supply Railway Traction Street Lighting PWW

Page 7


1.4 Transmission & Distribution losses

The Transmission & Distribution loss depends upon various factors such as

size of the network, energy demand, connected Load etc. The Transmission

Losses in the power system cannot be totally eliminated. However, efforts

are undertaken to reduce T&D loss to the desired permissible level.

Currently, DHBVN is serving consumers of which around are domestic

consumers.

Given below is a graph depicting the number of consumers across different

categories for the period from FY 2011-12 to FY 2017-18 (Up to July), It can

be seen that the number of consumers have increased over the period. The

majority of the consumers are in the LT-Domestic category followed by LT

Commercial Category.

Consumer Mix for last six years

Category FY 13 FY 14 FY 15 FY 16 FY 17 FY 18 (H1)

DOMESTIC 19,61,524 22,22,212 22,90,331 23,69,349 24,52,966 25,25,579

NON-DOMESTIC 2,28,923 2,56,616 2,68,741 2,82,654 2,95,444 3,02,684

LT INDUSTRIAL 44,204 47,010 48,403 49,073 49,619 49,747

HT INDUSTRIAL 5,624 6,340 6,494 6,804 7,052 7,348

AGRICULTURE METERED 1,59,789 1,94,999 2,06,679 2,11,062 2,16,106 2,19,771

24.74%

23.29%

24.25%

26.11% 26.45%

21.14%

23.71%

22.38%

23.66%

24.47% 24.47% 22.50%

FY 2011-12 FY 2012-13 FY 2013-14 FY 2014-15 FY 2015-16 FY 2016-17

TRANSMISSION & DISTRIBUTION LOSSES

AT&C T&D

Page 8


Category FY 13 FY 14 FY 15 FY 16 FY 17 FY 18 (H1)

AGRICULTURE UN-METERED 79,689 93,379 92,343 92,138 92,459 91,601

LIFT IRRIGATION 205 226 230 234 240 255

PUBLIC WATER WORKS 9,568 10,855 11,434 11,821 12,132 12,200

BULK SUPPLY 482 575 627 647 619 635

RAILWAYS 2 3 4 5 6 7

STREET LIGHT 783 917 1,004 1,127 1,206 1,226

TOTAL 24,90,793 28,33,132 29,26,290 30,24,914 31,27,849 32,11,053

DHBVN has been purchasing majority of its power from Central Generating

Stations (CGS) as per the allocation decided by Ministry of Power. The

purchase cost from FY 2011-12 to FY 2016-17 is based on audited accounts.

PER UNIT POWER PURCHASE COST

The figure depicts per unit rate of power purchase for DHBVN during last 6

years. The significant increase in power purchase cost is mainly on account

of huge dependence on external sources for purchase of power and the

increase in fuel cost of generating stations.

3.37

3.91

4.09 4.08 4.16

4.26

FY 2011-12 FY 2012-13 FY 2013-14 FY 2014-15 FY 2015-16 FY 2016-17

POWER PURCHASE (RS/KWH)

Page 9


1.5 Revenue

The revenue generated from the consumption of electricity to various

categories is shown in the chart below. Even though no. of consumers of HT

consumers is very few, the highest revenue is obtained from the HT

Industrial consumers i.e. of the total revenue. LT Domestic Category with

the highest no. of consumers generates only revenue.

Revenue from sale of power in the year FY 2016-17

1.6 HT-LT Ratio

The ratio of Secondary line length to its concerned Primary distribution line

length is one of the important factors that influence the performance of

primary distribution. Over the years, large scale expansion of the urban

system and rural electrification programme in the State of Haryana has

resulted in considerable expansion of High Tension (HT) distribution

network. The size of the distribution transformers has been constantly

increasing to meet the increasing demand due to load growth.

24%

19%36%

7%

2%1% 5% 1% 1% 4%

Domestic Non - Domestic HT Industry LT IndustryLift Irrigation Agriculture Bulk Supply Railway TractionStreet Lightning Public Water Works

Page 10


1.7 Regulatory Framework

The Hon’ble Commission had issued HERC (Terms and Conditions for

Determination of Tariff for Generation, Transmission, Wheeling and

Distribution & Retail Supply under Multi Year Tariff Framework)

Regulations, 2012 (herein MYT Regulations) notified on 5thDecember 2012

and 1st amendment on 7th November, 2016. However, the Hon’ble

Commission has not notified MYT Regulation for control period starting

from FY 2018-19 or extended the current MYT Regulation, 2012 to the year

FY 2018-19. In absence of any regulation for determination of ARR for FY

2018-19, MYT Regulations has been adopted.

The provisions of MYT Regulation 71.2.2 is as follows:

a) Sales / demand forecast for each consumer category and sub-categories

for each year of the control period and the methodology and rationale

used;

b) Power procurement plan based on the sales forecast and distribution loss

trajectory for each year of the control period. The power procurement

0.940.99

1.02

1.101.15 1.16 1.18 1.19

FY 2010-11 FY 2011-12 FY 2012-13 FY 2013-14 FY 2014-15 FY 2015-16 FY 2016-17 FY 2017-18 (H1)

HT:LT Ratio

Page 11


plan should also keep in view energy efficiency and demand side

management measures;

c) A set of targets proposed for other controllable items such as collection

efficiency, recovery of bad debts, working capital, quality of supply

targets etc. The targets shall be consistent with the capital investment

plan and business plan approved by the Commission;

d) Expected revenue from the licensed business, non-tariff income and

income from other business for the control period and other matters

considered appropriate by the distribution licensee(s);

e) Number of consumers in each category, connected load in kW and

estimate of the cost of supply for various consumer categories per kW

and per kWh

f) The ARR for various years of the control period, the revenue gap and

tariff proposal for meeting the revenue gap for last year of the control

period. The tariff proposal should be based on the cost of supply for

various consumer categories and the cross-subsidy reduction road map.

g) Proposal for meeting the projected cumulative revenue gap for last year

of the control period which shall include mechanism for meeting the

proposed revenue gap, tariff revision for various consumer categories

etc.

h) A statement of the effect of the proposed tariff changes on a typical small,

average and large consumer in each tariff class. For this purpose, a

typical small consumer is defined such that within the tariff class, 90%

of the consumers supplied under that tariff within a 12 month period

would have greater total expenditure on tariff charges than the small

consumer. Similarly, a typical large consumer is defined such that 90%

Page 12


of the consumers supplied under the tariff would have lesser

expenditure over a 12 month period than the typical large consumer. The

average consumer shall be defined as a consumer having expenditure on

tariff charges equal to the average expenditure in that tariff class.

1.8 Current petition

This petition for True-up of FY 2016-17, Annual Performance Review (APR)

for FY 2017-18 and Annual Revenue Requirement for FY 2018-19 is being

submitted by “Dakshin Haryana Bijli Vitran Nigam Limited”.

The current petition has been prepared in accordance with the provisions of

the following Acts/Policies/Regulations:

a) Electricity Act 2003;

b) National Electricity Policy;

c) National Tariff Policy;

d) HERC (Terms and Conditions for Determination of Tariff for Wheeling

and Distribution & Retail Supply under Multi Year Tariff Framework)

Regulations, 2012 and applicable current amendments;

e) HERC (Terms and conditions for grant of connectivity and open access

for intra-State transmission and distribution system) Regulations, 2012

and applicable current amendments;

DHBVN has made genuine efforts for compiling all relevant information

relating to this APR for FY 2017-18 and ARR & Tariff petition for FY 2018-19,

as required by the Regulations issued by the Hon’ble Commission and has

also made every effort to ensure that information provided to the Hon’ble

Commission is accurate and free from material errors. However, there may

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be certain deficiencies owing to the compilation of accounts of Petitioner

company and hence, DHBVN prays to the Hon’ble Commission that the

information provided be accepted for the current filing and at the same time

DHBVN assures that it is taking appropriate measures to improve its

management information system for improved data collection.

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Chapter 2. True-up of FY 2016-17

2.1 Principles of True Up for FY 2016-17

DHBVN is carrying out the true up exercise for FY 2016-17, based on audited

annual accounts of the Petitioner Company for the period from 1st April 2016

to 31st March 2017.

The Annual Accounts for the above period are submitted along with petition

as Annexure 1: Provisional Annual Accounts for FY 2016-17.

As per Para 4.2 of Haryana Electricity Regulatory Commission (Terms and

Conditions for Determination of Tariff for Generation, Transmission,

Wheeling and Distribution & Retail Supply under Multi Year Tariff

Framework) Regulations, 2012

“4.2 The Commission shall adopt Multi Year Tariff (MYT) framework

for determination of ARR/tariff for each year of the Control Period from

FY 2014-15. However, there shall be annual determination of

ARR/tariff for the utilities for FY 2013-14 for their respective businesses

as per these regulations.”

Hence, Hon’ble Commission shall undertake the True-up of Aggregate

Revenue Requirement of the Licensee for period of FY 2016-17, based on the

comparison of the actual performance of the year with the approved estimate

for the period of FY 2016-17.

It is submitted by the petitioner that approved figures presented in this

chapter for FY 2016-17 are taken from the HERC Order on Distribution &

Retail Supply ARR & Tariff of DHBVNL & DHBVN, dated 1st August, 2016.

Page 15


Accordingly, revised actual figures of expenditure, Aggregated Annual

Revenue Requirement, Revenue and Consequent Gap for FY 2016-17 is

provided in following paragraphs of this section.

2.2 Power Purchase and Power Purchase Cost

The Power Purchase operation for DHBVN is undertaken by an

administrative body called Haryana Power Purchase Cell (HPPC). The cell

is operated through representatives from both the Haryana Discoms. The

power requirement is met mainly through following resources:

i. NTPC

ii. NHPC

iii. NPC

iv. HPGCL

v. BBMB

vi. Open Access & Others

The details of power procured quantum and cost from various sources and

Commission approved quantum and cost for FY 2016-17 is shown in the

following table.

Page 16

Petition for True up of FY 2016-17, APR FY 2017-18 and ARR for FY 2018-19

Table 3: Power Purchase Details for FY2016-17

Power Purchase Source

Approved Power Purchase in Haryana for FY 2016-17

Actuals Power Purchase in FY 2016-17

Quantum in Mus

Total Power Purchase Cost

Rs. Million

UHBVN DHBVN Haryana

Units in MU Amount in Rs Million



NTPC

Singrauli STPS 1,482.38 2,789.53 516.309 1,102.01 686.40 1,451.19 1,202.71 2,553.20

Rihand I 450.37 1,165.62 136.727 377.78 183.15 502.62 319.88 880.39

Rihand II 437.50 1,103.78 159.118 395.26 212.44 522.48 371.56 917.74

Rihand III 398.90 1,165.45 144.101 472.99 192.73 627.61 336.83 1,100.60

Unchhahar I 39.11 166.25 19.034 88.12 25.08 117.67 44.11 205.79

Unchhahar II 86.29 367.69 45.878 197.05 59.97 260.32 105.85 457.37

Unchhahar III 47.49 237.24 24.788 117.60 32.58 155.38 57.37 272.97

Anta CCPP 60.34 321.52 15.568 94.35 19.71 122.55 35.28 216.90

Auraiya CCPP 98.03 536.11 10.864 110.10 13.60 144.94 24.47 255.04

Dadri CCPP 99.70 523.71 41.970 185.61 53.43 239.53 95.40 425.14

Faridabad CCPP 770.00 4,301.16 469.594 2,193.65 586.17 2,800.19 1,055.76 4,993.84

Farakka STPS 86.91 255.33 24.547 88.97 32.40 117.49 56.94 206.46

Kahalgaon I 108.71 424.78 50.792 195.10 68.02 258.62 118.81 453.72

Kahalgaon II 331.07 1,317.15 159.173 589.65 210.37 775.99 369.55 1,365.63

Kol Dam 141.47 831.38 139.952 627.92 168.15 790.20 308.10 1,418.12

NCTPS - -0.27 - -0.31 - -0.58

NHPC

Salal I 425.28 523.40 216.73 494.25 269.22 618.83 485.95 1,113.08

Page 17





Quantum in Mus


Rs. Million

UHBVN DHBVN Haryana




Bairasiul 191.32 422.45 85.72 188.61 109.75 244.40 195.48 433.01

Tanakpur 25.09 71.72 7.95 31.19 9.76 38.63 17.71 69.81

Chamera I 330.36 628.39 151.18 289.68 187.32 367.68 338.50 657.36

Chamera II 71.63 228.09 35.41 73.65 43.55 93.80 78.96 167.45

Chamera-III 80.08 401.39 35.45 159.56 42.56 197.75 78.01 357.31

Dhauliganga 54.72 172.69 23.72 73.69 28.83 93.04 52.54 166.73

Dulhasti 102.93 648.85 53.18 296.19 67.10 377.82 120.28 674.01

Uri 131.03 247.07 64.60 134.67 83.48 174.64 148.07 309.30

Uri-II 53.39 220.64 34.99 180.92 45.19 233.64 80.18 414.56

Sewa II 26.41 137.53 11.47 60.31 15.21 79.45 26.69 139.76

Parbati-III 58.84 326.62 26.56 151.59 31.89 184.48 58.45 336.07

SJVNL

SJVNL (NathpaJhakri) 286.40 890.75 134.08 391.82 164.09 496.88 298.16 888.70

SJVNL Rampur HEP 270.63 611.38 35.70 126.25 43.67 160.61 79.37 286.86

Tehri (THDC) 205.25 1,264.94 96.94 496.03 123.29 639.14 220.23 1,135.17

Koteshwar HEP 49.18 194.27 22.42 85.96 28.46 110.30 50.87 196.26

NAPP 199.40 486.72 82.62 212.95 110.39 284.52 193.01 497.47

RAPP (3-4) 591.80 1,631.71 226.69 691.87 301.11 918.11 527.80 1,609.98

RAPP (5-6) 239.73 820.67 - - - - - -

Others

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Quantum in Mus


Rs. Million

UHBVN DHBVN Haryana




HPGCL 17,252.66 75,294.82 3,852.02 20,284.45 5,027.96 26,201.24 8,879.99 46,485.69

BBMB 2,671.27 828.09 1,236.46 620.55 1,562.92 829.83 2,799.38 1,450.38

DVC Mejia-B 491.45 2,172.53 207.72 907.06 279.15 1,206.37 486.87 2,113.43

Koderma DVC 329.38 1,292.08 121.89 569.78 159.28 741.01 281.17 1,310.80

DVC Raghunathpur

71.13 330.74 71.37 257.91 93.77 341.27 165.14 599.18

CGPL, Mundra 2,503.22 5,972.29 985.69 2,326.16 1,329.37 3,118.00 2,315.06 5,444.16

Sasan UMPP 3,278.25 4,277.37 1,201.39 2,012.92 1,603.32 2,680.09 2,804.71 4,693.01

Tala, HEP 51.08 103.18 22.21 44.97 26.41 53.52 48.62 98.49

PTC GMR 1,692.00 2,909.55 882.88 2,287.83 1,180.21 3,056.11 2,063.09 5,343.94

PTC Baglihar 297.67 1,107.32 105.35 391.91 134.98 502.13 240.33 894.04

PTC Lanco Amarkantak 785.77 2,294.45 849.62 2,401.25 1,112.59 3,147.61 1,962.22 5,548.86

PTC Karchamwangtoo

841.50 2,853.64 358.32 1,459.45 434.09 1,851.22 792.41 3,310.67

IGSTPP, Jhajjar 1,116.12 12,619.92 1,204.58 7,217.97 1,600.37 9,516.75 2,804.95 16,734.71

Pragati Gas Bawana - - 79.25 640.89 104.93 854.61 184.19 1,495.50

Adani Power Ltd. 9,169.56 29,425.11 4,271.26 13,861.14 5,665.18 18,340.32 9,936.44 32,201.46

Teesta III 86.48 345.92 - - - - - -

MGSTPS, CLP, Jhajjar

4,803.43 24,589.67 1,056.79 6,818.47 1,441.44 9,116.56 2,498.23 15,935.03

Small Hydro

Bhoruka 18.21 57.91 11.51 36.57 - - 11.51 36.57

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Quantum in Mus


Rs. Million

UHBVN DHBVN Haryana




P&R Gogripur 6.07 26.47 6.62 28.85 - - 6.62 28.85

Puri Oil Mill 8.50 34.72 17.92 73.14 - - 17.92 73.14

HPSEB/MITTAL SMALL HYD. 623.39 2,929.95 761.19 3,577.58 1,384.58 6,507.53

Biomass Projects 186.18 1,145.01 90.75 688.14 93.91 711.31 184.66 1,399.45

Cogeneration Plants 110.38 378.60 44.76 181.23 25.72 104.13 70.48 285.36

Solar Plants 156.12 868.96 66.80 366.77 96.64 537.12 163.45 903.89

PGCIL Transmission Charges

8,967.28 - 5,997.63 - 7,896.77 - 13,894.41

BANKING POWER 1,696.31 7,192.35 1,946.53 8,253.27 3,642.84 15,445.63

Short Term 0.08 0.15 0.11 0.22 0.19 0.37

UI - - - - - -

PGCIL-UI -13.09 248.40 -21.13 321.57 -34.22 569.97

HVPNL-UI - - - - - -

SLDC and Open Acess charges - 1,393.96 - 2,797.26 - 4,191.23

Total PP Cost 53,958.17 2,03,331.61 22,355.67 92,214.95 28,908.03 1,19,956.06 51,263.70 2,12,171.01

Prior Period 3,620.23 3,328.23 6,948.47

Total PP Cost Excluding HVPN Charges 53,958.17 2,03,331.61 22,355.67 95,835.19 28,908.03 1,23,284.29 51,263.70 2,19,119.48

HVPN Transmission Charges - 6,726.02 - 6,729.21 - 13,455.24

Total PP Cost incl. of all charges 53,958.17 2,03,331.61 22,355.67 1,02,561.21 28,908.03 1,30,013.50 51,263.70 2,32,574.71

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Table 4: Power Purchase Details for FY-2016-17 for Haryana (in MU)

Haryana Power Purchase

Approved Actual Difference

Power Purchase Quantum 53958.17 51263.70 2694.47

Further, it is submitted that average actual per unit cost comes out at Rs. 4.26 per

unit; higher than the average approved per unit cost of Rs. 3.77 per unit; the actual

average per unit cost is higher than approved levels due to increase in actual power

purchase cost from various sources as compared to approved.

The appellant submits herewith that in actual for FY 2016-17, the power allocation

ratio is 44% and 56% for UHBVN and DHBVN respectively. The petitioner would

like to submit that even actual power purchases are in line with the approval by

Hon’ble Commission.

The Petitioner prays to the Hon’ble Commission to approve the actual power

purchase quantum of 28,908.03 MU and associated power purchase cost

Rs. 13,001.35 Crore of DHBVN for FY 2016-17 as per the Annual Accounts as

summarized in the table above.

2.3 Energy Balance

The Energy Balance for FY 2016-17 is shown below:

Table 5: Energy Balance for FY 2016-17

Particulars Unit FY 2016-17

Total Power purchase * Mus 28,908.03

Sale outside the State including Banking &UI Mus 2,279.22

Purchase for sale within the state (a-b) Mus 26,628.82

Less Transmission losses Mus 1,065.70

Transmission Losses % 3.69%

Power available for sale Mus 25,563.11

Sales within the state (excluding Agriculture) Mus 14,197.40

Sales within the state - Agriculture Mus 5,614.52

Page 21


Particulars Unit FY 2016-17

Total Sales* Mus 19,811.92

Distribution Loss % 22.50%

DHBVN requests the Hon’ble Commission to approve the same.

2.4 Operation & Maintenance Expenses

The Operation & Maintenance Expenses of the company includes

• Employee Expenses;

• Repair & Maintenance Costs and

• Administrative and General Expenses.

Employee Expense consists of salaries, dearness allowance, bonus, terminal

benefits in the form of pension & gratuity, leave encashment and staff welfare

expenses.

Repairs and Maintenance Expenses go towards the day to day upkeep of the

distribution network of the Company and form an integral part of the

Company’s efforts towards reliable and quality power supply as also in the

reduction of losses in the system.

Administrative expenses mainly comprise of rents, telephone and other

communication expenses, professional charges, conveyance and travelling

allowances and other debits.

A comparison of Actual against the approved Net O&M Expenses (after

deducting the capitalization) is highlighted in the following table.

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Table 6: O&M Expenses for FY 2016-17 (Rs. Crore)

Particulars Approved Actual Difference

Employee Expense 629.03 669.34 40.31

Administration & General Expense 73.86 82.18 8.32

Repair & Maintenance Expense 132.77 68.23 (64.54)

Terminal Liability 335.38 420.00 84.62

Total 1,171.04 1,239.76 68.98

As seen from the table above; the total O&M Expenses for FY 2016-17 have been

provided along with the approved expenses for the year. DHBVN prays the

Hon’ble Commission to approve the same.

2.5 Employee Expenses

The ‘Employees cost' includes the cost incurred by the distribution licensees on

their employees who are presently working as well as for their retired

employees. The cost of working employees includes salary, dearness allowance

and other allowances such as HRA, CEA, LTC, medical reimbursement etc.

However, in case of retired employees and those who would retire during the

year, the distribution licensees have to discharge financial liabilities towards

pension, gratuity, leave encashment benefit etc.

DHBVN has incurred Terminal Benefits of Rs. 420 Crore, Basic salary expenses

of employees as Rs. 191.64 Crore dearness allowance expense of employees as

Rs. 230.16 Crore, and Rs 109.40 Crore as other allowances.

The summary of the actual employee expenses for FY 2016-17 vis-à-vis the

expenses approved by the Hon’ble Commission has been given in the table

below:

Table 7: Employee Expenses for FY 2016-17 (Amt. in Rs. Crore)


Basic Salary 629.03 191.64 (49.70)

Page 23



Dearness Allowance (DA) - 230.16

Expenditure on Contract Employees - 147.54

Other allowance - 109.40

Terminal benefits 335.38 420.00 (84.62)

Gross Employee Expense 964.61 1,098.73 (134.32)

Less Expenses Capitalised - 9.39 9.39

Net Employee Expenses 964.61 1,089.34 124.93

DHBVN prays the Hon’ble Commission to approve the actual Employee

Expense for FY 2016-17 of Rs. 1089.34 Crore against the approved expense of

Rs. 964.61 Crore per the details given in above table.

2.6 Repair & Maintenance Expenses

Repair and Maintenance expenditure is dependent on various factors. R&M

cost is meant for the upkeep of the system. Every asset requires repair and

maintenance at some point and in order to keep the system healthy and running

the Petitioner has to incur substantial amount on R&M to keep its assets

running. DHBVN has been trying its best to ensure uninterrupted operations

of the system and accordingly has been undertaking necessary expenditure for

R&M activities to keep the system health and maintain the quality indices.

The summary of the comparison of the actual R&M expenses for FY 2016-17 vis-

à-vis the expenses approved by the Hon’ble Commission has been given in the

table below:

Table 8: R&M Expenses for FY 2016-17 (Amount in Rs. Crore)

Particulars Approval Actual Difference

Repair and maintenance Expenses 132.77 68.23 (64.54)

It is submitted that as per the available accounts of FY 2016-17, the R&M

expenses, work out to be Rs. 68.23 Crore, which is computed as 1.00% of Avg.

GFA for FY 2016-17.

Page 24


DHBVN prays the Hon’ble Commission to approve the actual R&M Expense

for FY 2016-17 of Rs. 68.23 Crore against the approve expense of Rs. 132.77

Crore as per the details given in above table.

2.7 Administrative & General Expenses

The actual A&G Expense for FY 2016-17 is Rs. 82.18 Crore against Rs. 73.86

Crore as approved by the Hon’ble Commission. There is a slight increase in the

A&G expenses incurred over the approved level.

The summary of the comparison of the actual A&G expenses for FY 2016-17 vis-

à-vis the expenses approved by the Hon’ble Commission has been given in the

table below:

Table 9: A&G Expenses for FY 2016-17 (Rs. Crore)


Gross A&G Expenses 73.86 90.43 16.57

Less: Expenses Capitalised - 8.25 8.25

Net A&G Expenses 73.86 82.18 8.32

DHBVN prays the Hon’ble Commission to approve the actual A&G Expense

for FY 2016-17 of Rs. 82.18 Crore as per the details given in above table.

2.8 Capital Expenditure

The Hon’ble Commission approved a Capital Expenditure of Rs. 1200.00 Crore

for DHBVN for FY 2016-17. As per the audited accounts of DHBVN for FY 2016-

17; the Capital Expenditure for DHBVN for FY 2016-17 is Rs. 640.93 Crore.

DHBVN, thus requests the Hon’ble Commission to approve the same.

2.9 Interest Cost on long term loans

The Hon’ble Commission has allowed an amount of Rs. 81.89 Crore as interest

cost on borrowings for FY 2016-17. However, the Gross Interest on Capex Loans

Page 25


in actual were Rs. 214.10 Crore, with interest capitalised being Rs. 119.50 Crore

and Net Interest on Capex Loans being Rs. 94.60 Crore.

2.10 Interest on Working Capital and Borrowings

The Hon’ble Commission has allowed the interest on borrowings for working

capital as per the MYT Regulation. In case of DHBVN, Hon’ble Commission

had approved the working capital requirement of Rs. 1023.31 Crore. @Interest

rate of 11.30% on this borrowing amount to Rs. 108.00 Crore. However, the

interest on borrowings for working capital as per actual are Rs. 842.97 Crore as

per the audited accounts for FY 2016-17.

2.11 Interest on Consumer Security Deposits

The Hon’ble Commission has allowed Rs. 26.63 Crore as interest on consumer

security deposit for FY 2016-17. However, the actual expenses under this head

work out to be Rs. 18.63 Crore

DHBVN thus prays to the Hon’ble Commission to approve the actual Expense

for interest on consumer security deposit for FY 2016-17 as per the details given

above.

2.12 Interest on Bonds

It is submitted that Government of India has notified Ujwal Discom Assurance

Yojana (UDAY) scheme for operational and financial turnaround of power

distribution companies (DISCOMs), on 20th Nov 2015 under which State shall

take over 75% of Discom debt as on 30th September, 2015 over two years – 50%

of Discom debt shall be taken over in FY 2015-16 and 25% in FY 2016-17. The

schedule of takeover of loan has been given as under:

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Break up of State Govt Takeover of Loans

Particulars FY 16 FY 17 FY 18 FY 19 FY 20

Grant (%) 11.25% 11.25% 11.25% 11.25% 11.25%

Grant (Cr) 3,892.5 3,892.5 3,892.5 3,892.5 3,892.5

Equity (%) 3.75% 3.75% 3.75% 3.75% 3.75%

Equity (Cr)

1,297.5 1,297.5 1,297.5 1,297.5 1,297.5

Debt (%) 35.00% 45.00% 30.00% 15.00% 0.00%

Debt (Cr) 12,109.9 15,569.9 10,379.9 5,190.0 0.0

The Amount taken over by the Government of Haryana will been converted

into grant in 5 tranches and in the meantime the interest cost of such bonds

which has not been converted into grants by the GoH has to be borne by the

Licensee only.

The Licensee in the FY 2016-17 has borne interest cost of Rs 461.21 Cr total

Interest on UDAY bonds.

Before UDAY, the interest on FRP bonds was borne by the Government of

Haryana, However, after the UDAY scheme the same is being borne by the

Licensee. In the FY 2016-17, an expense of Rs 0.12 Cr has been incurred by the

licensee to service the cost of FRP bonds.

Also, an amount of Rs 73.88 has been paid toward HVPN Bonds.

2.13 Total Interest & Finance Cost

The total Interest Expense as per the audited annual accounts of DHBVN for

FY 2016-17 vis-à-Vis approved by the Hon’ble Commission is shown in the table

below:

Table 10: Total Interest & Finance Cost for FY 2016-17 (Rs. Crore.)

Category Approved Actual

Gross Interest on Capex Loans 81.89 214.10

Less: Interest Capitalized 119.50

Net Interest on Capex Loans 81.89 94.60

Page 27


Category Approved Actual

Interest on Working Capital Loans 108.00 307.78

Interest on FRP Borrowings 0.12

Interest on HVPNL Bonds 73.88

Interest on UDAY Loans 461.21

Interest on Consumer Security Deposits 26.63 18.63

Other Interest and Finance charges 3.53

Total 216.52 959.74

DHBVN prays the Hon’ble Commission to approve the actual interest & finance

expenses for FY 2016-17 as per the details provided in the table given above.

2.14 Depreciation

The Hon’ble Commission, in its order approved a net depreciation of Rs. 267.62

Crore after adjusting for depreciation on consumer’s contribution.

The actual opening GFA for FY 2016-17 is at Rs. 6,610.84 Crore and closing

balance is at Rs. 7,067.83 Crore; the corresponding gross depreciation for FY

2016-17 works out to be Rs. 300.42 Crore and net depreciation (after adjusting

for depreciation on consumer’s contribution and grants of Rs. 84.94 Crores)

comes out at Rs. 215.49 Crore. The Hon’ble Commission is requested to approve

the same.

2.15 Return on Equity

As per the available annual accounts of DHBVN for FY 2016-17; the RoE works

out to be Rs. 281.17 Crore. However, the Hon’ble Commission has been

disallowing any returns on equity in the past. The Petitioner would like to

submit that as per the Hon’ble APTEL Judgment dated 18th April, 2012 on

Appeal No. 102 of 2011, HVPNL was allowed ROE as per Regulation 17 of the

HERC (Terms and conditions for determination of transmission tariff)

Regulations, 2008, i.e. @ 14% per annum.

Page 28


Further it is submitted that not allowing any returns to the Nigam would result

in financial burden and financial stress to Nigam; therefore, the Hon’ble

Commission is requested to approve the return on equity @ 14% to the

distribution licensees as well.

2.16 Non – Tariff Income

The Non – Tariff Income approved by Hon’ble Commission for DHBVN in FY

2016-17 was Rs. 170.01 Crore. As per the available annual accounts of DHBVN

for FY 2015-16; the Actual Non-Tariff Income comes to Rs. 542.86 Crore.

The Nigam has not considered the delayed payment surcharge for FY 2016-17.

The Nigam submits that delayed payment surcharge is collected against the

receivables from the consumers that are not received in time. As there is a delay

in receiving the revenue, the Nigam has to procure additional working capital.

Therefore, the revenue received on account of delayed payment surcharges is

not income of the Nigam, rather it’s a carrying cost recovered from consumers

to pay the interest on the increased portion of working capital which occur

because of delay in receiving the revenue. Therefore, it is requested that the

revenue from delayed payment surcharge should not be considered as income

of the Nigam.

The Hon’ble Commission is requested to approve the same.

2.17 Expenditure due to other debts

It is submitted that as per the annual accounts of DHBVNL, there is an amount

of Rs. 200.28 Crore which includes amount Rs. 170.96 Cr on account of provision for

bad and doubtful debts, recorded under the head of other debts. The amount

consists of expenditure on account of revenue amount refunded, misc. losses

and written off amount as well as amount of unrealised surcharge from

consumer.

Page 29


The Hon’ble Commission is requested to approve the same for FY 2016-17.

2.18 True up of RE subsidy

The total agricultural sales approved by the Hon’ble Commission in FY 2016-

17 were 9094 MU and against the same a subsidy of Rs. 5933.54 Crore for

DHBVN and DHBVN was allowed. This amounts to a per unit subsidy of Rs.

6.52/unit. Based on the feeder data, the actual agricultural sales, following

HERC methodology of 16% losses on AP Feeder data emerges to 4066.68 MU

for DHBVN and 5034.95 MU for DHBVN.

Therefore, for total sales of 9101.64 MU, the eligibility of subsidy emerges to Rs.

5,938.52 Crores (9101.64 MU*Rs. 6.52 per unit). Consequently, post true up, the

outstanding subsidy emerges to Rs. 4.98 Crore.

Table 11: True up of RE subsidy for FY 2016-17

Particulars FY 2016-17

Total RE subsidy allowed by HERC in Tariff order for 2016-17 (Rs Crs) 5,933.54

Total Agricultural sales approved by HERC in T.O (Mus) 9,094.00

Approved Per unit Subsidy (Rs./unit) 6.52

Agriculture Sales based on Feeder data minus 16% losses (Mus) UHBVN 4,066.68

Agriculture Sales based on Feeder data minus 16% losses (Mus) DHBVN 5,034.95

Agriculture Sales based on Feeder data minus 16% losses (Mus) 9,101.64

Eligibility of subsidy based on actual sales of 2016-17 (Rs. Crs) 5,938.52

Subsidy Outstanding/(Surplus) (Rs. Crs) 4.98

2.19 Summary of True up of FY 2016-17

The table below provides an overview of the difference between the approved

expenditure for FY 2016-17 under consideration vis-à-vis the actual expenditure

incurred by the Nigam.

Thus, the difference in approved and actual expenditure as per the summary

table below for DHBVN and DHBVN may be allowed to the distribution

licensees along with separate allocation of RE subsidy to the Discoms for FY

2016-17.

Page 30


Table 12: True Up of Expenses for FY 2016-17 (Rs. Crore)

Particulars Approved Actual Deviation

Total Power purchase cost 11,300.79 13,001.35 (1,700.56)

Power Purchase Expenses incl Inter State Transmission 10,632.55 12,328.56

Intrastate transmission charges and SLDC charges 668.24 672.79

Operations and Maintenance Expenses 1,171.04 1,239.76 (68.72)

Employee Expense 629.03 669.34

Administration & General Expense 73.86 82.18

Repair & Maintenance Expense 132.77 68.23

Terminal Liability 335.38 420.00

Depreciation 267.62 215.49 52.13

Total Interest & Finance Charges 216.52 959.74 (743.22)

Return on Equity Capital - 281.17 (281.17)

Other Expenses - 200.28 (200.28)

Total Expenditure 12,955.96 15,897.78 (2,941.82)

Less: Non-Tariff Income 170.01 542.86 (372.85)

Net Aggregate Revenue Requirement 12,785.95 15,354.92 (2,568.97)

Total Revenue 12,348.03

Revenue from Interstate sales 749.80

Revenue from Intrastate sales / Sale of Power 9,451.83

Revenue from FSA 2,146.40

Net Gap (3,006.89)

AP-Subsidy 3,965.32 2,643.54

GAP After AP Subsidy (363.34)

It is submitted that the Licensee has submitted the Expenses of FY 2016-17 based

on the actual annual accounts of FY 2016-17. Since the Hon’ble Commission in

its Tariff Order dated 1st August, 2016 has not provided bifurcation of some of

the revenue items between DHBVN and DHBVN, hence it is requested that the

Hon’ble Commission may kindly approve the appropriate Gap based on the

expenses and revenue as per annual accounts.

Further, the Hon’ble Commission has allowed a revenue Gap of Rs 672.14 Cr

along with holding cost of Rs 168.14 Cr in ARR of FY 2016-17. The final revenue

gap on account of True-up amounting to Rs. 2240.15 Cr along with carrying cost

Page 31


has been taken forward in the approved ARR for the FY 2018-19.

Table 13: Final True up of FY 2016-17 in Rs Cr.

Particulars Amount in

Rs. Cr

True-Up of DHBVN after Subsidy (632.67)

True-Up of DHBVN after Subsidy (363.34)

Total True-Up Amount (996.01)

Revenue GAP FY 2014-15 approved by HERC (672.14)

Approved Carrying cost on above for 1 year and six months (168.04)

Total True-Up Amount (1,836.19)

Holding Cost (403.96)

True-Up Amount along with the holding cost (2,240.15)

Page 32


Chapter 3. Annual Performance Review for FY 2017-18 and Annual Revenue Requirement for FY 2018-19

3.1 Preamble

This chapter deals with the revised estimates for FY 2017-18 against that

approved by the Hon’ble Commission Tariff Order dated 11th July, 2017. In

order to undertake Annual Performance Review for FY 2017-18 on approved

Annual Revenue Requirement for FY 2017-18 and estimates for FY 2018-19,

various assumptions and other practical approaches have been taken into the

consideration. The same has been described in detail, while projecting each

component.

3.2 Capital Expenditure

The Hon’ble Commission vide order dated 11th July, 2017 has approved a Capex

Plan of Rs 1100 Cr. for FY 2017-18. DHBVN has estimated to undertake an

expenditure of Rs 1100 Cr as approved by the Hon’ble Commission in FY 2017-

18. In order to achieve the loss targets as proposed in the following chapters,

DHBVN propose a Capital Expenditure of Rs 1300 Cr for FY 2018-19.

The funding of capital expenditure in FY 2017-18 and FY 2018-19 is being

arranged by debt from REC, PFC and supported further from equity and

consumer contribution. The table below reflects the funding arrangement of

capital expenditure during the control period.

Table 14: Summary of funding of capital expenditure in FY 2017-18 and 2018-19

Capitalization Schedule FY 2017-18 FY 2018-19

Percentage Transfer of Capex into fixed asset 60% 60%

Percentage Transfer of Capex into CWIP 40% 40%

Total 100% 100%

Page 33


Further, the Details of Scheme wise CAPEX for the FY 2018-19 has been given

in the table below:

Table 15: Scheme Wise details for the FY 2018-19

Sr. No. Categories Quantity Unit Rate

(In Rs.) CAPEX

(Rs. In Cr)

1 AT&C loss reduction plan

a

Procurement of single phase meters for replacement of defective meters & release of new connections and procurement of Smart Meters.

7,30,000 Nos.

683 50.00

b

Procurement of three phase meters for replacement of defective meters & release of new connections and procurement of Smart Meters.

1,75.000 Nos.

1687 30.00

c Power Factor Improvement (Providing automatic power factor correctors)

16.00

d Providing of LT Capacitors on 400 KVA and above Distribution Transformers

33.00

2 Load Growth schemes

a Creation of new 33 kV sub-stations along with associated 33 kV & 11 kV lines

55 Nos. 3,00,00,000 150.00

b Augmentation of existing 33 kV sub-stations 57 Nos. 25,00,000 14.00

c Augmentation of existing 33 kV lines 70 KM 7,00,000 5.00

d Bifurcation of 11 kV feeders (Work of bifurcation of feeders, augmentation of ACSR).

391 Nos. 25.00,000 50.00

e Material required for release of Non-AP connections & replacement of old assets

171.00

f Release of Tube well connection on turnkey basis and segregation of AP load from Rural Urban feeders.

5000 Nos. 1,25,000 62.00

g

Procurement of power transformers and allied equipment such as 33 kV CTs, 33 kV PTs, 33 kV and 11 kV VCBs, 33 kV Control and Relay Panels etc.

45 Nos. (10 MVA)

05 Nos. (12.5 MVA)

4200000 (10 MVA)

5300000 (12.5 MVA)

28.00

H

Release of BPL connections under RGGVY schemes. Work already awarded for Palwal (9163 BPL Connections), Gurugram (2882 BPL Connections) and Faridabad (1494 BPL Connections) Circles on 15.11.2016, 31.01.2017 and 02.03.2017 respectively. Approximately 90% work likely to be completed in FY 2017-18 and provision has been made for taking care of remaining/residual works.

4.00

i 11 KV Lines 535.96 kms 21.98

j Distribution Transformer (63,100, 200

kVA) 850 Nos. 15.20

k LT ABC Line 182 kM 8.49

Page 34



(In Rs.) CAPEX

(Rs. In Cr)

l

Augmentation- DTR, Existing line on

conductor to ABXLPE, Augmentation of

11kV lines

157/926/771 11.90

m Metering (3 phase), Solar Energy Meter 2524 Nos. 1.46

n Solar Project 103 Nos. 0.84

3 R-APDRP schemes

a Implementation of R-APDRP (Part-A) 8.80

4 Other works

a

Maintenance free earthling using 'Ground Enhancing Material' for Distribution Transformers, Meter Pillar Boxes and H-pole etc.

6000 Nos.

5,000 3.00

b

Installation of meters on 33 kV Incomers at sub-stations for energy auditing. Work already awarded on 02.06.2017. Approximately 40% work already completed and provision has been made for taking care of remaining works.

350 Sub-Stations.

2.00

c Civil Works 10.00

d

Shifing of HT line (33 kv), passing over authorized/un-authorized colonies under jurisdiction of DHBVN. Note:-Hon’ble Chief Minister has made an announcement on the floor of Haryana Vidhan Sabha that all dangerous wires of 33 KV and above levels passing over the various colonies shall be removed. Accordingly, Worthy ACS/Power, Govt. of Haryana, Power Deptt. directed to prepare the detailed scheme in this regar. Also, Worthy ACS/Power, Govt. of Haryana, Power Deptt. has desired that it may be made part of the CAPEX Plan and approval of HERC be obtained.

7 Nos. 33 KV lines under Rewari and

Narnaul Circles

5.00

e Mahara Gaon Jagmag Gaon scheme for rural area and feeder sanitization for Urban area/LRP/Replacement of iron pole.

190.00

f Other works for system improvement - Procurement of IT Equipment & Softwares

8.00

g Smart City Gurgaon (HT & LT Lines, DTs, U/G Cables, RMUs and FRTUs Etc.) including SCADA Project, IMT, Manesar (Rs. 24 Crores)

235.00

h Smart City Faridabad, Hisar & Rewari (HT & LT Lines, DTs, U/G Cables, RMUs and FRTUs Etc.)

68.00

i Shifting of 11 lines passing over residential areas under DHBVN.

20.00

J Works under EESL (Smart Meters) 220000 Nos. 2500 55.00

Total 1277.67

B) CAPEX under UDAY (Ujjwal DISCOM Assurance Yojana)

Page 35



(In Rs.) CAPEX

(Rs. In Cr)

1

Scaling of IT project to Non-RAPDRP areas covering the following: - 1. Establishment of IT infra in SDO & Other offices and its connectivity with Data Centre. 2. AMR for Non-RAPDRP feeders. 3. DT metering for 2953 in Non-RAPDRP areas. 4. AMR for HT & LT CT operated meters. Total DPRs cost for the above works is Rs. 20.55 Crores and approximately, 60% expenditure is likely to be incurred during FY 2018-19.

12.33

2 Boundary meters for Villages in Rural Areas (3648 number of villages i.e. 7296 meters)

3648 meters 40000 10.00

Total 22.33

Grand Total 1300.00

3.3 Transmission and Distribution Losses.

The Hon’ble Commission vide its Tariff Order dated 11.07.2017 has approved a

AT&C loss of 22.48% for DHBVN for the FY 2017–18 which is in accordance

with the targets laid down in the UDAY MoU. Against the committed AT&C

losses of 22.48% % for FY 2016-17 in the UDAY MoU, the Discoms have been

able to achieve actual AT&C loss level of 21.14%. Further, as per the UDAY,

MoU both the Discoms were required to achieve an AT&C loss level of 15% for

the FY 2018-19. As such a loss reduction of approx. 6% has to be achieved during

the current financial year to meet the UDAY targets.

In view of above, DHBVN has considered a realistic AT&C target of 18.76% for

FY 2017-18 and 15.00% for the FY 2018-19.

3.4 Capital Work in Progress

Capital work in progress (CWIP) has been calculated as shown below:

Table 16: Summary of CWIP (Rs. Crore)

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

Actual Actual Projected Projected

Opening CWIP 829.19 989.61 1,137.38 894.95

Page 36


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

Actual Actual Projected Projected

Add: Capex during year 587.88 640.93 1,100 1,300

Capex Capitalized 427.45 493.16 1,342.43 1,316.97

IDC during the year

Closing CWIP 989.61 1,137.38 894.95 877.98

3.5 Assessment of Energy Sales for 2017-18 and 2018-19

In order to estimate the respective consumer category wise energy sales of

DHBVNL for FY 2017-18 and FY 2018-19, the Petitioner has relied upon the

CAGR of previous year’s data of sales. The sales of the base year i.e. FY 2016-17

has been considered for projection of category wise sales to the consumers.

Similarly, category wise connected load has been projected for the FY 2017-18

and FY 2018-19 based on the CAGR of 3 to 5 years. The methodology applied

by the petitioner for estimating the metered sales is as under: -

• Category wise CAGR of energy sales is calculated. The energy sales for FY

2017-18 and FY 2018-19 is calculated by the escalating the energy sales of FY

2016-17 by CAGR of 3-5 years

• Agriculture consumption for FY 2017-18 and FY 2018-19 is calculated by

assuming a growth rate of 5% in sales over FY 2015-16.

• For determination of sales of railways for FY 2017-18 a nominal increase of

5% in sales is considered on second half sales of FY 2015-16 to determine the

sales for remaining half. However, for FY 2018-19, sales is computed on the

basis of load and specific consumption derived from FY 2016-17. Reduction

in load of equivalent to 50% has considered as railway would be option for

medium term open access in FY 2018-19.

Hence, keeping the above basis, DHBVNL envisages the expected sales figures

as shown in following table:

Page 37


Table 17: Statement of sales for FY 2017-18 and FY 2018-19 (Mus)

Category FY 2016-17

Actual FY 2017-18 Approved

FY 2017-18 FY 2018-19

Domestic 4,589.16 5,313.18 4,797.79 5,141.09

Non-Domestic 2,548.65 2,943.24 2,768.39 3,006.65

HT Industry 4,521.60 5,028.86 4,936.99 5,162.83

LT- Industry 898.95 1,098.62 934.65 976.44

Lift Irrigation 148.29 148.18 166.20 174.51

AP Sales 5,034.95 5,053.00 5,286.70 5,551.04

Bulk Supply 676.60 641.63 712.81 727.62

Railways 197.45 184.86 201.31 143.73

Street Light 91.79 95 91.18 95.74

PWW 524.91 596.11 589.04 643.75

Total 19,232.35 21,102.68 20,485.07 21,623.39

DHBVNL request Hon’ble Commission to approve energy sales, as per revised

projections for FY 2017-18 and FY 2018-19 tabulated above.

3.6 Energy Availability for Haryana for FY 2017-18 and FY 2018-19

For FY 2017-18 and FY 2018-19, Month Wise Energy availability at the state

periphery in MU has been projected based on the Allocated Share to Haryana

of Central Generating Stations, State Generation and Independent Power

Producers and other Stations.

The Energy Availability in Haryana is calculated based on the average PLF of

FY 2016-17, FY 2015-16 and FY 2014-15, Share capacity of Haryana from Central

Generating Station IPP and various other sources. The energy availability to

DHBVN is calculated by multiplying the total availability with the ratio of

drawal of UHBVN and DHBVN.

The Monthly energy sale is determined by distributing the same in the

percentage of month of consumption of FY 2016-17. The energy sales hereby

projected has been grossed up with the losses approved under UDAY scheme

to reach at the normative energy required at the Discom periphery and then by

the intrastate transmission losses to arrive at the normative energy required at

the State Periphery.

Page 38


Then the Normative energy required at the State is assumed to be met through

the Available Energy from Must Run Plant i.e. plants which cannot be backed

down like Hydro Power Plants, Solar Power Plant and Biomass.

The remaining demand is met through the Thermal Power Plant i.e. HPGCL,

IPPs and NTPC as per the Merit order dispatch based upon the Variable charges

as per the actual bills of FY 2016-17.

The Impact of Interstate losses on the Inter State Generating station has already

been taken while calculating the availability at the state periphery.

The Backing Down of the Unit is assumed to be limited to the backing down

capacity and any surplus created on account of same is assumed to be banked

with other states and consumed during next financial year.

The Actual Variable Charges of FY of FY 2016-17 has been escalated at an

average rate of 5% per year to arrive and multiplied with the total estimated

energy drawn from various generators to arrive at the total variable cost of

power generation for FY 2017-18, however for FY 2018-19 the variable cost has

been kept at same levels as that of FY 2017-18. The same has been projected in

view of Licensee’s attempt for better power purchase planning, load forecasting

and coal rationalizing as per UDAY scheme.

Similarly, the fixed charges paid to the generators in FY 2016-17 are escalated

at an average rate of 5% to arrive at the fixed charges to be paid for FY 2017-18

and FY 2018-19.

For FY 2017-18, the approved per unit cost of power purchase from HPGCL as

approved by the Hon’ble Commission has been considered. Further, in FY 2018-

19, The Generation from various units of HPGCL and their cost is based on the

inputs received from HPGCL. Further, the utility reserves the right to change

Page 39


the filed numbers based on the outcome of the Tariff Order on the Tariff petition

filed by HPGCL.

Further, the Hon’ble CERC through its various judgements has allowed certain

generators like Adani Power, and CGPL recoveries on account of change in law

etc. It is submitted that Licensee has already made payment of Rs. 1508.14 Cr,

therefore the same has been included in the power purchase cost of FY 2017-18.

Further, the monthly impact based on the bills of Adani power on account of

above works out to Rs 0.52 per unit, accordingly the licensee has increased the

per unit cost of power purchase for the purpose of estimation of Cost of power

purchase from Adani Power in FY 2017-18 and FY 2018-19.

The additional power purchase cost due to the impact of Hon’ble CERC

Judgment works out to Rs 657.69 cr for UH and Rs 850 .45 Cr for DH

respectively which has been added in the overall projected power purchase cost

in FY 2017-18.

Page 40


Table 18: Power Purchase Quantum Availability and Costs – Projected for FY 2017-18 and FY 2018-19

Sr. No

Project FY 2017-18

Total Charges

FY 2018-19 Total

Charges Quantum Energy Charge

Fixed Charges

Quantum Energy Charge

Fixed Charges

1 Anta 32.87 9.33 7.52 16.84 32.87 9.79 7.89 17.68

2 Auriya 15.94 5.76 10.31 16.07 15.94 6.05 10.83 16.87

3 Dadri 55.68 17.38 9.32 26.70 55.68 18.25 9.78 28.04

4 Faridabad Gas 672.30 168.28 134.95 303.22 672.30 176.69 141.69 318.39

5 Feroz Gandhi Unchahar-1 37.26 11.24 4.51 15.75 37.26 11.80 4.74 16.54



8 Farraka Super Thermal 32.99 9.58 3.77 13.35 32.99 10.06 3.95 14.02

9 Kahalgaon-1 84.02 22.10 10.09 32.19 84.02 23.21 10.59 33.80

10 Kahalgaon-2 234.12 59.18 30.87 90.04 234.12 62.13 32.41 94.55

11 Koldam 179.85 40.60 45.18 85.77 179.85 42.62 47.43 90.06

12 NCTPS (DADRI-II) - - -0.03 -0.03 - - -0.04 -0.04

13 Rihand Thermal Power St.-1 232.06 31.39 22.11 53.50 232.06 32.96 23.22 56.18



16 Singrauli Super Thermal 773.77 115.61 49.63 165.24 773.77 121.39 52.11 173.50

17 TOTAL NTPC LTD (A) 2,881.74 582.21 397.35 979.55 2,881.74 611.32 417.21 1,028.53

Page 41


Sr. No

Project FY 2017-18

Total Charges

FY 2018-19 Total


Fixed Charges


Fixed Charges

18 NHPC

19 BAIRASUIL 116.23 11.64 14.25 25.89 116.23 12.22 14.96 27.18

20 SALAL 273.07 16.55 17.66 34.22 273.07 17.38 18.55 35.93

21 TANAKPUR 10.46 1.70 2.58 4.28 10.46 1.79 2.71 4.50

22 CHAMERA-I 206.12 23.14 18.33 41.47 206.12 24.30 19.25 43.55

23 URI 87.53 7.35 7.37 14.73 87.53 7.72 7.74 15.46

24 CHAMERA-II 46.42 4.78 5.34 10.13 46.42 5.02 5.61 10.63

25 DHAULIGANGA 28.31 4.45 5.22 9.67 28.31 4.67 5.48 10.15

26 DHULHASTI 67.46 19.54 18.21 37.75 67.46 20.52 19.12 39.64

27 SEWA-II 17.37 3.91 4.56 8.47 17.37 4.10 4.79 8.89

28 CHAMERA III 41.43 9.14 11.35 20.49 41.43 9.60 11.92 21.52

29 PARBATI III 27.51 7.83 7.76 15.59 27.51 8.22 8.15 16.37

30 URI-II 38.70 9.72 13.23 22.95 38.70 10.20 13.90 24.10

31 TOTAL NHPC LTD (B) 960.59 119.76 125.87 245.63 960.59 125.75 132.16 257.91

32 SJVNL 165.70 21.00 27.79 48.79 165.70 22.05 29.18 51.23

33 SJVNL (RAMPUR) 38.69 6.49 9.49 15.97 38.69 6.81 9.96 16.77

34 THDC 107.80 30.26 31.11 61.38 107.80 31.77 32.67 64.44

35 THDC KOTESHWAR 28.47 5.79 5.90 11.69 28.47 6.08 6.20 12.28

36 RAPS 307.61 81.88 0.03 81.91 307.61 85.97 0.04 86.01

37 NAPS 102.55 27.54 0.01 27.55 102.55 28.92 0.01 28.92

Page 42


Sr. No

Project FY 2017-18

Total Charges

FY 2018-19 Total


Fixed Charges


Fixed Charges

38 BBMB 1,596.58 93.62 - 93.62 1,596.58 98.30 - 98.30

39 PTC TALA 26.20 5.88 - 5.88 26.20 6.18 - 6.18

40 PTC J&K 161.43 62.44 - 62.44 161.43 65.56 - 65.56

41 Aravali Co. Pvt. Ltd. 1,437.03 425.51 463.60 889.11 1,433.33 445.63 486.78 932.41

42 JHAJJAR POWER LTD. 2,003.02 668.61 469.84 1,138.44 2,008.77 704.05 493.33 1,197.38

43 PRAGATI POWER 188.57 52.00 60.94 112.94 188.57 54.60 63.99 118.59

44 Coastal Gujrat Power Ltd. 1,367.98 195.71 142.54 338.25 1,367.98 205.50 149.66 355.16

45 ADANI POWER LTD 5,627.46 1,528.98 613.49 2,142.47 5,627.46 1,605.43 644.16 2,249.59

46 SASAN POWER LIMITED 1,691.19 246.70 30.11 276.81 1,691.19 259.03 31.62 290.65

47 PTC GMR KAMALANGA 1,185.56 119.98 182.70 302.68 1,185.56 125.98 191.83 317.81

48 PTC KARCHAMWANGTOO 431.09 82.34 107.91 190.25 431.09 86.45 113.31 199.76

49 PTC Lanco Amarkantak 1,037.65 170.35 144.39 314.75 1,037.65 178.87 151.61 330.48

50 DVC MEJIA 265.28 59.47 64.53 123.99 265.28 62.44 67.75 130.19

51 DVC KODERMA 154.55 30.56 41.98 72.55 154.55 32.09 44.08 76.17

52 DVC Raghunathpur 358.70 90.89 14.32 105.21 358.70 95.43 15.04 110.47

53 PTPS-V (HPGCL) 310.90 136.67 45.85 182.53 310.90 143.51 48.15 191.65

54 PTPS-VI (HPGCL) 313.84 114.86 52.46 167.33 312.37 120.04 55.08 175.13

55 PTPS-VII (HPGCL) 897.68 315.89 109.46 425.36 897.68 331.69 114.93 446.62

56 PTPS-VIII (HPGCL) 883.41 335.34 99.59 434.94 883.41 352.11 104.57 456.69

57 YTPP-I&2 (HPGCL) 1,669.65 563.01 247.17 810.18 1,670.27 591.38 259.53 850.91

Page 43


Sr. No

Project FY 2017-18

Total Charges

FY 2018-19 Total


Fixed Charges


Fixed Charges

58 RGTPS 1&2 (HPGCL) 2,218.37 776.65 477.98 1,254.63 2,200.91 809.06 501.88 1,310.94

59 WYC Kakaroi 172.62 37.39 3.10 40.49 172.62 39.26 3.26 42.51

60 HPGCL (FSA) - - - - - - - -

61 SLDC CH. OF HPGCL - - - - - - -

62 OTHER LONG TERM ( C) 24,749.59 6,285.80 3,446.32 9,732.12 24,733.32 6,594.19 3,618.63 10,212.83

63 P&R GOGRIPUR small hydro 5.48 2.18 - 2.18 5.48 2.29 - 2.29

64 Bhoruka Power Corps. Ltd. Small hydro 16.43 5.21 - 5.21 16.43 5.47 - 5.47

65 HPSEB/MITTAL SMALL HYD. - - - - - - - -

66 Megahalya/ APPC - - - - - - - -

67 SHAHBAD SUGAR MILL 91.12 36.90 - 36.90 91.12 38.75 - 38.75

68 CH. DEVI LAL SUGAR MILL - - - - - - - -

69 Haryana Co. Sugar Mill. - - - - - - - -

70 Hafed Sugar Mill - - - - - - - -

71 Meham Sugar Mill - - - - - - - -

72 Puri Oil Mill small hydro 7.67 3.06 - 3.06 7.67 3.21 - 3.21

73 SUGAR MILL AND SMALL HYDRO (D) 120.70 47.36 - 47.36 120.70 49.72 - 49.72

74 SDS SOLAR PVT LTD. DH 0.94 0.53 - 0.53 0.94 0.56 - 0.56

75 C&S Electrical DH 0.94 0.53 - 0.53 0.94 0.56 - 0.56

76 CHANDRALEELA SOLAR DH 0.75 0.43 - 0.43 0.75 0.45 - 0.45

77 SUKHBIR SOLAR DH 0.94 0.53 - 0.53 0.94 0.56 - 0.56

Page 44


Sr. No

Project FY 2017-18

Total Charges

FY 2018-19 Total


Fixed Charges


Fixed Charges

78 ZAMIL SOLAR DH 0.94 0.53 - 0.53 0.94 0.56 - 0.56

79 SIWANA SOLAR POWER DH 4.69 3.02 - 3.02 4.69 3.17 - 3.17

80 H.R. MINERAL SOLAR UH 0.94 0.54 - 0.54 0.94 0.57 - 0.57

81 TAYAL & CO SOLAR UH 0.94 0.53 - 0.53 0.94 0.56 - 0.56

82 VKG SOLAR UH 0.94 0.53 - 0.53 0.94 0.56 - 0.56

83 Utrecht Solar Pvt. Ltd. 0.94 0.53 - 0.53 0.94 0.56 - 0.56

84 Subhash Infra Engineers Pvt ltd. 0.94 0.54 - 0.54 0.94 0.57 - 0.57

85 HPGCL-Solar 9.39 4.58 - 4.58 9.39 4.81 - 4.81

83 Solar Energy Corporation of India Ltd. 75.09 41.30 - 41.30 75.09 43.36 - 43.36

84 SOLAR POWER (E) 98.36 54.14 - 54.14 98.36 56.84 - 56.84

85 STAR WIRE INDIA 24.65 19.21 - 19.21 24.65 20.17 - 20.17

86 GEMCO ENERGY LTD. 19.92 16.13 - 16.13 19.92 16.94 - 16.94

87 AB GRAIN SPIRIT PVT LTD. 12.45 9.59 - 9.59 12.45 10.06 - 10.06

88 SRI JYOTI 23.65 18.21 - 18.21 23.65 19.12 - 19.12

89 BIOMASS POWER (F) 80.67 63.14 - 63.14 80.67 66.30 - 66.30

90 Total Long term (A+B+C+D+E+F) 28,891.65 7,152.40 3,969.53 11,121.93 28,875.38 7,504.12 4,168.01 11,672.13

91 New Plants (FY 2017-18)

92 JBM Solar 18.77 10.66 - 10.66 18.77 11.20 - 11.20

93 Unchahar IV (NTPC) 56.81 16.80 6.58 23.38 56.81 17.64 6.91 24.55

94 Bio-Mass based Generation Projects 8.69 6.80 - 6.80 17.43 14.32 - 14.32

Page 45


Sr. No

Project FY 2017-18

Total Charges

FY 2018-19 Total


Fixed Charges


Fixed Charges

95 Bagasse Nariangarh Sugar mill 31.04 24.28 - 24.28 62.24 51.13 - 51.13

96 Kishanganga (J&K)- NHPC 24.90 4.26 2.83 7.09 49.95 8.96 5.95 14.91

97 Kotli Bhel (All 3 Stages) (Uttranachal)-NHPC 76.02 13.00 8.65 21.64 152.47 27.37 18.16 45.53

98 Solar Power Projects at wasteland of HPGCL-1 10.30 5.85 - 5.85 20.65 12.31 - 12.31

99 Teesta III, Sikkim (IPP) , Hydro 262.15 44.81 29.82 74.63 525.74 94.37 62.62 156.99

100 New Plants (FY 2018-19) 488.68 126.46 47.88 174.34 904.05 237.30 93.64 330.94

101 Parbati II, HEP (H.P.)-NHPC 58.98 10.59 7.05 17.63

102 Solar Power Projects at wasteland of HPGCL-2 7.35 4.39 - 4.39

103 66.34 14.97 7.05 22.02

104 Total Cost of Power Purchase 29,380.32 7,278.86 4,017.41 11,296.27 29,845.76 7,756.39 4,268.69 12,025.08

105 Hon'ble APTEL Judgement 850.45 850.45 -

106 Total Cost of Power Purchase 29,380.32 7,278.86 4,867.86 12,146.73 29,845.76 7,756.39 4,268.69 12,025.08

Page 46


The Nigam prays that in case of any variance in the cost of new plants, the

Nigam should be allowed to recover the additional cost.

Further, the Nigam has projected the Interstate and Intrastate Transmission

charges for FY 2018-19 by escalating the Interstate and Intrastate Transmission

charges approved by the Hon’ble during for FY 2017-18 by 3.32% which is rate

of escalation considered by Hon’ble CERC for escalating the transmission

charges. The summary of same is given below:

Table 19: Summary of Power Purchase in Rs Cr.

Particular FY 2017-18 FY 2018-19

Power Purchase Cost 11,296.27 12,025.08

Interstate Transmission Cost 790.39 843.74

Intra-state Transmission Cost 904.36 934.38

Prior Period Expenses (CERC Decision) Already Paid in FY 2017-18

850.45 -

Total Power Purchase Cost 13,841.47 13,803.21

The total power purchase cost from external and state sources for DHBVN

including impact of CERC Judgment has been assessed at Rs. 13,841.47 Crores

for FY 2017-18 and Rs. 13,803.21 Crores for 2017-18.

3.7 Transmission losses

For FY 2017-18 and FY 2018-19, the inter-state transmission losses and intra-

state transmission losses have been considered as 3.82% and 2.46% respectively

as approved by the Commission.

3.8 Energy Balance – DHBVNL

On the basis of the above projections, the Energy Balance for DHBVN for FY

2017-18 and FY 2018-19 is summarized below.

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Table 20: Energy Balance for DHBVN

Energy Balance Units FY 2017-18 FY 2018-19

Energy Sales to the Consumers Mus 20,485.07 21,623.39

T&D loss %age 17.94% 14.14%

Energy Input at Discom Periphery Mus 24,963.52 25,184.90

Intra- State Transmission Loss %age 2.46% 2.46%

Energy Input at State Periphery Mus 25,593.11 25,820.07

Total Energy Available Mus 37,534.46 38,401.61

Inter-state Power Purchase considering MoD Mus 12,081.46 12,522.36

Inter State transmission losses %age 3.82% 3.82%

Inter-state Power Purchase at State Periphery Mus 11,619.95 12,044.01

Intra state Power Purchase Considering MoD Mus 17,760.37 17,801.76

Power Purchase at State Periphery Mus 29,380.32 29,845.76

Surplus Mus 3,787.21 4,025.69

The Nigam has assumed that the surplus power available will be sold entirely

as ‘inter-state sales’ throughout FY 2017-18 and FY 2018-19 at 80% of average

variable power purchase cost.

DHBVN request the Hon’ble Commission to approve the above submission for

FY 2017-18 and FY 2018-19.

The Petitioner also submits the bulk supply tariff computed for DHBVN as

given below:

Table 21: Bulk Supply Tariff for DHBVN

Bulk Supply Tariff Units FY 2017-18 FY 2018-19

Net energy available at state boundary for use in

DHBVN Mus 29,380.32 29,845.76

Intra-state transmission losses % 2.46% 2.46%

Intra-state transmission losses Mus 722.76 734.21

Energy available for sale to distribution licensee

at its periphery Mus 28,657.57 29,111.56

Power purchase cost Rs Cr 11,296.27 12,025.08

Inter-state transmission charges Rs Cr 790.39 843.74

Page 48


Bulk Supply Tariff Units FY 2017-18 FY 2018-19

Intra-state transmission charges Rs Cr 904.36 934.38

Prior Period Expense Rs Cr 850.45 -

Total bulk purchase and transmission charges Rs Cr 13,841.47 13,803.21

Power purchase per unit at Generator Ex-bus Rs/Kwh 3.94 4.13

Inter-state transmission charges Rs/Kwh 0.28 0.29

Intra-state transmission charges Rs/Kwh 0.32 0.32

Prior Period Expense Rs/Kwh 0.30 -

Average BST for DHBVN Rs/Kwh 4.83 4.74

3.9 Operation & Maintenance Expenses

The operation and maintenance expenditure of DHBVNL comprises of

Employee Expenses, Repair & Maintenance expenses and Administration &

General expenses. The O&M expenses, as per the MYT regulations, 2012 are

considered as controllable factor with the exception of terminal benefits. The

cost of terminal benefits has been considered as uncontrollable factor.

The MYT Regulations have clearly set out the methodology to calculate the

O&M expenses for the Distribution and Retail supply business for the control

period, the same is reproduced below:

The actual audited O & M expenses for the financial year preceding the

base year, subject to prudence check, shall be escalated at the escalation

factor of 4% to arrive at the O & M expenses for the base year of the control

period. The O&M expenses for the nth year of the control period shall be

approved based on the formula given below.

O&Mn = (R&Mn + EMPn + A&Gn)* (1-Xn) + Terminal

Liabilities

Where,

• R&Mn – Repair and Maintenance Costs of the Distribution

Licensee(s) for the nth year;

Page 49


• EMPn – Employee Costs of the Distribution Licensee(s) for the nth

year excluding terminal liabilities;

• A&Gn – Administrative and General Costs of the Distribution

Licensee(s) for the nth year;

The above components shall be computed in the following manner.

(a) R&Mn = K * GFA * INDXn/ INDXn-1

Where,

• ‘K’ is a constant (expressed in %) governing the relationship between

O&M costs and Gross Fixed Assets (GFA) for the nth year. The value

of K will be 1.65% for DHBVN and DHBVN respectively for the

entire control period;

• ‘GFA’ is the average value of the gross fixed asset of the nth year.

• ‘INDXn’ means the inflation factor for the nth year as defined herein

after.

(b) EMPn (excluding terminal liabilities) + A&Gn = (EMPn-1+ A&Gn-

1)*(INDXn/ INDXn-1)

Where,

• INDXn – Inflation Factor to be used for indexing the Employee Cost

and A&G cost. This will be a combination of the Consumer Price

Index (CPI) and the Wholesale Price Index (WPI) for immediately

preceding year and shall be calculated as under:

• INDXn = 0.55*CPIn +0.45*WPIn

Note 1: For the purpose of estimation, the same INDXn value shall be

used for all years of the control period. However, the Commission shall

consider the actual values of the INDXn at the end of each year during the

Page 50


annual performance review exercise and true-up the employee cost and

A&G expenses on account of this variation.

Note 2: Any variation in employee cost and A&G cost on account of

reasons beyond variation in INDXn shall be subject to the incentive and

penalty framework specified in regulation 12.

Note 3: As and when any material price index specific to power sector or

a more relevant Index becomes available, the same shall replace the Index

used for working out R&M cost.

Note 4: Terminal liabilities shall be approved as per actual expenditure

incurred by the distribution licensee or established through actuarial

valuation for the ensuing year.

Note 5: O&M expenses made on account of extraordinary situations (if

any) shall be submitted to Commission for its approval. Such expenses

shall be filed separately and will not be subjected to incentive and penalty

framework. The approved amount by the Commission shall be trued up in

the annual performance review.

Note 6: Changes in the pay scales of employees necessitated on account of

pay revision by Pay Commission or by the State Government orders shall

be considered by the Commission for true-up during the annual

performance review.

(c) Xn is an efficiency factor for nth year

The Value of Xn will be determined by the Commission in the MYT order

for the control period.

3.10 Computation of Inflationary Indices

The computation of applicable Inflationary Indices for the projection of

O&M expenses and its sub-heads are as under:

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Table 22: Inflation factor for WPI & CPI

WPI Inflation

Financial Year Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar Average

FY 2017-18 113.2 112.9 112.7 113.9 114.8 113.5

FY 2016-17 109 110.4 111.7 111.8 111.2 111.4 111.5 111.9 111.7 112.6 113 113.2 111.6

FY 2015-16 110.2 111.4 111.8 111.1 110.0 109.9 110.1 109.9 109.4 108 107.1 107.7 109.7

FY 2014-15 114.1 114.8 115.2 116.7 117.2 116.4 115.6 114.1 112.1 110.8 109.6 109.9 113.9

CPI Inflation

Financial Year Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar Average

FY 2017-18 277 278 280 285 285 281.0

FY 2016-17 271 275 277 280 278 277 278 277 275 274 274 275 275.9

FY 2015-16 256 258 261 263 264 266 269 270 269 269 267 268 265.0

FY 2014-15 242 244 246 252 253 253 253 253 253 254 253 254 250.8

Inflation Faction WPI CPI Total

Weightage 0.45 0.55 1.00

Average Indexation for FY16-17 113.50 281.00

Average Indexation n-1 (Index * Wt.) 51.08 154.55 205.63

Average Indexation for FY15-16 111.62 275.92

Average Indexation n (Index * Wt.) 50.23 151.75 201.98

Combined Inflation (Indxn. /Indxn-1) 1.80%

DHBVNL submits herewith that as per the calculations tabulated above, the

applicable combined inflation indices, after taken considerations of weightage

average ratios of WPI & CPI of 45:55 of FY 2016-17 and FY 2017-18 has been

computed as 1.80 %, and the same has been put into the calculations of O&M

Expenses, discussed in consecutive paras of this submission.

3.11 Employee Expenses

The employee expenses primarily include costs towards salaries, dearness

allowances, bonus, staff welfare and medical benefits, leave travel and earned

leave encashment, and the terminal benefits in the form of pension, gratuity etc.

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The Inflation Index of 1.80% as indicated in above table has been considered

over FY 2016-17 to arrive at employee cost for FY 2017-18 and FY 2018-19. The

petitioner has projected Employee Expense of Rs 884.90 Cr and Rs 820.03 Cr

respectively.

The petitioner has also projected the amount paid for terminal benefits, as Rs.

301 Crores for FY 2017-18 and Rs 343.25 Cr for FY 2018-19.

Further, an additional increase of 12% has been assumed in the employee cost

on account of 7th pay commission recommendations. Hence, the employee cost

for

FY 2017-18 has been escalated by 3% on normative value and Rs 90 Cr. Has been

added as onetime expense towards payments for arrears of 7th Pay

Commission.

Table 23: Employee Expenses for FY 2018 and FY 2018-19 (Amt. in Rs. Crores)

Particulars FY 2017-18 FY 2018-19

Salaries 576.58 501.18

Dearness Allowance 24.33 25.06

Other Allowances 296.41 305.30

Terminal benefits 301.00 343.25

Gross Employee Expense 1,198.32 1,174.79

Less Expenses Capitalised 12.42 11.51

Net Employee Expenses 1,185.90 1,163.28

We request the Hon’ble Commission to approve total employee cost for FY

2017-18 and FY 2018-19 as per above tabulated computation.

3.12 Repair & Maintenance Expanses

The petitioner has projected R&M expenses for FY 2017-18 and FY 2018-19, as

per the formula specified in HERC MYT regulations, 2012 and same has been

quoted again as below:

(a) R&Mn= K * GFA * INDXn / INDXn-1

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Where,

• ‘K’ is a constant (expressed in %) governing the relationship between O&M

costs and Gross Fixed Assets (GFA) for the nth year. The value of K will be

1.65% for DHBVN and DHBVN respectively for the entire control period;

• ‘GFA’ is the average value of the gross fixed asset of the nth year.

• ‘INDXn’ means the inflation factor for the nth year as defined herein after.

The petitioner has projected R&M expenses for FY 2017-18 and FY 2018-19, on

the applicable/ approved average GFA of DHBVNL with the appropriate

inflation factor i.e. 1.80%, tabulated as below:

Table 24: R&M Expenses for FY 2018 and FY 2018-19 (Amt. in Rs. Crores)

Particulars FY 2017-18 (Projected)

FY 2018-19 (Projected)

Average GFA for Previous Year 7,715.28 8,993.11

K factor 1.65% 1.65%

Indexation % 1.80% 1.80%

R&M Expenses 129.60 151.06

R&M Expense has been projected @ 1.80% inflation factor for FY 2017-18 and as per MYT Regulations 2012, the K factor being considered 1.65% at average GFA

We request the Hon’ble Commission to approve total R&M expenses for FY

2017-18 and FY 2018-19 as per above submission.

3.13 Administration & General Expenses

Administration and General expenses mainly comprise costs towards rent

charges, telephone and other communication expenses, professional charges,

conveyance and travelling allowances and other debits.

As per MYT Regulations, 2012, the Inflation factor of 1.80% has been considered

over FY 2016-17 to arrive at A&G cost for FY 2017-18 and FY 2018-19. The

computation of A&G cost considering expenses works out to as below:

Page 54


Table 25: A&G Expenses for FY 2018 and FY 2018-19 (Amt. in Rs. Crores)


Gross A&G Expenses 90.43 92.07

Indexation (%) 1.80% 1.80%

Net A&G Expenses 92.07 93.73

Less: Expenses Capitalised 8.40 8.55

Administrative and General Expense 83.67 85.18

DHBVN prays the Hon’ble Commission to approve total A&G expenses for FY

2017-18 and FY 2018-19 as per above submission.

3.14 Summary of O&M Expanses

The summary of projected O&M expenses for FY 2017-18 and FY 2018-19 is

tabulated below for reference:

Table 26: Summary of O&M Expenses for FY 2018 and FY 2018-19 (Amt. in Rs. Crores)

Particulars FY 2017-18 (Projected)

FY 2018-19 (Projected)

Employee Expense 884.90 820.03

A&G Expense 83.67 85.18

R&M Expense 129.60 151.06

Terminal Benefits 301.00 343.25

Total O&M Expenses 1,399.16 1,399.52

DHBVN prays the Hon’ble Commission to approve total O&M expenses for FY

2017-18 and FY 2018-19 as tabulated above.

3.15 Interest & Finance Charges

As per Regulation 21 of HERC (Terms and Conditions for Determination of

Tariff for Generation, Transmission, Wheeling and Distribution & Retail

Supply under Multi Year Tariff Framework) Regulations, 2012; Interest on

Loan Capital for existing loans shall be computed loan-wise and for new loans

it shall be equal to the base rate of SBI as applicable on 1st April of the relevant

financial year. The relevant regulations are provided here for ease of reference:

Page 55


Regulation 21.1 Existing Loans

(i) Interest on loan capital shall be computed loan-wise for existing loans

arrived in a manner specified in Regulation 19 and shall be as per the

rates approved by the Commission.

(ii) The loan outstanding as on 1 s t April of each financial year shall be

worked out as the gross loan in accordance with regulation 19 by

deducting the cumulative repayment as admitted by the Commission up

to 31st March of previous financial year from the gross normative loan;

(iii) The rate of interest shall be the weighted average rate of interest on

institutional loans calculated on the basis of the actual loan portfolio at

the beginning of each year applicable to the project. In case the weighted

average rate is not available, the interest rate approved by the Commission

in its earlier tariff order shall be allowed.

Provided that if there is no actual loan for a particular year but normative

loan is still outstanding, the last available weighted average rate of interest

shall be considered;

Provided further that if the generating plant/project does not have actual

loan, then the weighted average rate of interest of the generating

company/licensee as a whole shall be considered

(iv) The interest on loan shall be calculated on the normative average loan

of the year by applying the weighted average rate of interest;

(v) The generating company and the licensee shall from time to time review

their capital structure i.e. debt and equity and make every effort to

restructure the loan portfolio as long as it results in net savings on

interest. The costs associated with such re- financing shall be borne by the

beneficiaries and the net savings (after deducting the cost of re- financing)

Page 56


shall be subjected to incentive / penalty framework as mentioned in the

regulation 12 which shall be dealt with at the time of mid-

year performance review/true-up.

(vi) The changes to the loan terms and conditions shall be reflected from the

date of such re- financing and benefit passed on to the beneficiaries;

(vii) In case of any dispute relating to re-financing of loan, any of the parties

may approach the Commission with proper application along with all the

relevant details. During the pendency of any dispute, the beneficiaries

shall not withhold any payment on account of orders issued by the

Commission.

(viii) In case any moratorium period on repayment of loan is availed of by

the generating company or the licensee, depreciation provided for in the

tariff during the years of moratorium shall be treated as repayment during

those years and interest on loan capital shall be calculated accordingly.

Regulation 21.2 New Loans (on or after 6th April 2013)

(i) Rate of interest on new loans shall be equal to the base rate of SBI as

applicable on 1st April of the relevant financial year plus an appropriate

margin that realistically reflects the rate at which generating company or

the licensee can raise loans from the market. They shall however, be required

to submit due justification to the Commission for the terms and conditions

of the loans raised by them.

Provided that interest and finance charges on works in progress shall be

excluded and shall be considered as part of the capital cost;

Provided further that neither penal interest nor overdue interest shall be

allowed for computation of Tariff

Page 57


(ii) Any variation above or below the allowed interest rate shall be subject

to the incentive and penalty framework specified in regulation 12.

(iii) The amount of loan shall be arrived in the manner as specified in

regulation 19 and shall be based on the approved capital investment plan.

(iv) In case any moratorium period on repayment of loan is availed of by the

generating company or the licensee, depreciation provided for in the tariff

during the years of moratorium shall be treated as repayment during those

years and interest on loan capital shall be calculated accordingly.

Interest on Capex Loan to be raised for the ensuing control period:

It is estimated that 78% of the CAPEX i.e. Approved CAPEX Rs 1100 Cr. for FY

2017-18 and Rs 1300 Cr for FY 2018-19 would be made through loans from

various Lending agencies. It is estimated that the fresh loans would be serviced

at the rate of 11.50% per year. The Detailed calculation of interest on CAPEX loan

has been given at the Table: 28 and 29

Interest on Consumer Security Deposit:

Payable @ 6.50% (per annum on average opening and closing balance. The

petitioner submits that Interest on Security Deposit amount has been claimed as

per the provision of MYT Regulations, 2012.

As per Para 21.4 of MYT Tariff Regulations, dated 26/12/2012,

“Interest shall be allowed on the amount held as security deposit held in cash from

Transmission System Users, Distribution System Users and Retail consumers, at the

Bank Rate as on 1st April of the financial year in which the petition is filed provided

it is payable by the transmission/distribution licensee. “

The details of Interest on the Consumer Security Deposit has been given in the

table below:

Page 58


Table 27: ICD of FY 2017-18 and FY 2018-19

Description FY 2016-17 FY 2017-18 FY 2018-19

No. of consumer 31,27,872 32,34,438 33,45,382

Deposit per consumer 3,667.57 3,569.80 3,618.69

Security Deposit 1,147.17 1,154.63 1,210.59

Interest Rate 1.62% 6.50% 6.50%

Interest on security deposit 18.63 74.81 76.87

Interest Capitalized:

It is based on proportion of 60% of the asset capitalized over the opening CWIP

and capex added during the year;

Interest on Working Capital Loan:

It is also pertinent to mention that the Government of India has notified Ujwal

Discom Assurance Yojana (UDAY) scheme for operational and financial

turnaround of power distribution companies (DISCOMs), on 20th Nov 2015

under which State shall take over 75% of Discom debt as on 30th September,

2015 over two years – 50% of Discom debt shall be taken over in FY 2015-16 and

25% in FY 2016-17. The implementation of UDAY leads to changes in the

projections of interest and finance charges for the Discoms which had an impact

on the revenue requirement of the Discoms.

It is submitted that the first tranche of UDAY bonds against 50% of the debt as

on 3.9.2015 amounting to Rs. 17300 crore has been issued, after the finalization

of the loans to be taken over under this tranche and the terms and conditions of

the UDAY bonds. Now the second tranche has also been taken over towards

25% of the debt amounting to Rs. 8650 crore.

The major provisions of the UDAY scheme that have been taken into the

account while preparing the revised ARR:

Page 59


➢ 75% of outstanding debt as on 30.09.2015 to be taken over in the form of

equity / loan / Grant to DISCOMS.

➢ Take-over in year 1: 50%, Year 2: 25%

➢ Take-over assumed at the end of second quarter from year 2

➢ Total Loan of Rs. 13003 Crore for DHBVN has been assumed to be taken

over by the Govt. of Haryana under UDAY scheme including the FRP

loans as well as HVPNL liabilities.

➢ The Bonds have been issues at an coupon rate of 8.21%

➢ ROI of balance 25% loan: Base rate+0.1% w.e.f. 01.04.2016 at present 9.80%

(Bank rate of lead bank (OBC).

Therefore, in order to operationally and financially turnaround the discoms, the

Hon’ble Commission must consider the interest on the UDAY Bonds and loan

considered under UDAY and other loan as the interest of the same is borne by

the license and the disallowance of it would lead to unnecessary financial

burden on the already financially distressed discoms. The Details of the year

wise Interest has been given in the table below:

Nov-17 Page 60


Table 28: Loan Profile and interest Liability of the Nigam for FY 2017-18 (Amount in Crores)

01.04.2017 to 30.09.2017 OB ROI Planned Receipt

Principal Repayment

CB Int.

Charges 01.10.2017 to 31.03.2018 OB ROI

Planned Receipt

Principal Repayment

CB Int.

Charges

CAPEX LOAN (A)

PMGY (GOH) 0.57 11.25% - 0.04 0.53 0.03 PMGY (GOH) 0.53 11.25% - 0.04 0.49 0.03

APDRP (GOH) 21.14 11.50% - 1.51 19.63 1.17 APDRP (GOH) 19.63 11.50% - 1.40 18.23 1.09

REC (Term Loan) 1,643.28 11.50% 360.93 117.38 1,886.83 101.49 REC (Term Loan) 1,886.83 11.50% 360.93 134.77 2,112.99 114.99

PFC Term Loan 1.16 9.00% - 0.77 0.39 0.03 PFC Term Loan 0.39 9.00% - 0.39 - 0.01

PFCL (R-APDRP) 82.46 9.00% - 5.89 76.57 3.58 PFCL (R-APDRP) 76.57 9.00% 35.00 5.47 106.10 4.11

REC (RGGVY) 5.19 11.50% - 0.37 4.82 0.29 REC (RGGVY) 4.82 11.50% - 0.34 4.47 0.27

World Bank Loan 181.56 1.25% - 12.97 168.59 1.09 World Bank Loan 168.59 1.25% 37.80 12.04 194.35 1.13

JICA Loan - 0.80% - - - - JICA Loan - 0.80% 63.34 - 63.34 0.13

Commercial bank for Electrification schemes

128.05 10.60% - 9.15 118.91 6.54 Commercial bank for Electrification schemes

118.91 10.60% - 8.49 110.41 6.08

Total CAPEX Loan (A) 2,063.42 10.53% 360.93 148.08 2,276.27 114.23 Total CAPEX Loan (A) 2,276.27 10.46% 497.07 162.95 2,610.39 127.84

WORKING CAPITAL LOAN (B)

PFC-STL - 10.25% 100.00 - 100.00 2.56 PFC-STL 100.00 10.25% - 50.01 49.99 3.84

REC-MTL - 12.00% 100.00 100.00 - 3.72 REC-MTL - 12.00% - - - -

HVPNL Bonds 1 293.40 9.45% - - 293.40 13.86 HVPNL Bonds 1 293.40 9.45% - - 293.40 13.86



DHBVN Bonds @ 9.80% 162.86 9.80% - - 162.86 7.98 DHBVN Bonds @ 9.80% 162.86 9.80% - - 162.86 7.98

UDAY Tranche 1 4,707.51 8.21% - - 4,707.51 193.24 UDAY Tranche 1 2,756.48 8.21% - - 2,756.48 113.15

UDAY Tranche 2 978.43 8.18% - - 978.43 40.02 UDAY Tranche 2 978.43 8.18% - - 978.43 40.02



Bonds (HVPNL) 1 61.51 9.79% - - 61.51 3.01 Bonds (HVPNL) 1 61.51 9.79% - - 61.51 3.01

Nov-17 Page 61



Principal Repayment

CB Int.

Charges 01.10.2017 to 31.03.2018 OB ROI

Planned Receipt

Principal Repayment

CB Int.

Charges


State Govt. Loan 31.03.2016

921.25 8.21% - - 921.25 37.82 State Govt. Loan 31.03.2016

526.43 8.21% - - 526.43 21.61


230.50 8.18% - - 230.50 9.43 State Govt. Loan 15.06.2016

230.50 8.18% - - 230.50 9.43


9.13 8.14% - - 9.13 0.37 State Govt. Loan 30.06.2016

9.13 8.14% - - 9.13 0.37


23.58 8.06% - - 23.58 0.95 State Govt. Loan 04.07.2016

23.58 8.06% - - 23.58 0.95

FRP Bonds 188.19 9.80% - - 188.19 9.22 FRP Bonds 188.19 9.80% - - 188.19 9.22

Cash Credit Limit 142.47 10.55% 5.77 - 148.24 7.67 Cash Credit Limit 148.24 10.55% 201.76 - 350.00 13.14

Loan from GoH - 7.26% 350.00 - 350.00 6.35 Loan from GoH 350.00 7.26% - 350.00 - 6.35

OFR Funding - 8.21% - - - - OFR Funding - 8.21% 1,759.18 - 1,759.18 36.11

Total WC Loan (B) 8,238.30 4.25% 555.77 100.00 8,694.07 359.43 Total WC Loan (B) 6,348.21 4.24% 1,960.94 400.01 7,909.14 302.28

Grand Total (A+B) 10,301.72 4.45% 916.70 248.08 10,970.34 473.67 Grand Total (A+B) 8,624.49 4.49% 2,458.01 562.96 10,519.53 430.12

Nov-17 Page 62


Table 29: Loan Profile and Interest Liabilities of the Nigam for FY 2018-19 (Amount in Crores)


Principal Repayment

CB Int. 01.10.2018 to 31.03.2019 OB ROI Planned Receipt

Principal Repayment

CB Int.

CAPEX LOAN (A)

PMGY (GOH) 0.49 11.25% - 0.04 0.46 0.03 PMGY (GOH) 0.46 11.25% - 0.03 0.42 0.02

APDRP (GOH) 18.23 11.50% - 1.30 16.93 1.01 APDRP (GOH) 16.93 11.50% - 1.21 15.72 0.94

REC (Term Loan) 2,112.99 11.50% 402.50 150.93 2,364.56 128.73 REC (Term Loan) 2,364.56 11.50% 402.50 168.90 2,598.17 142.68

PFC TL - 9.00% - - - - PFC TL - 9.00% - - - -

PFCL (R-APDRP) 106.10 9.00% 9.00 7.58 107.53 4.81 PFCL (R-APDRP) 107.53 9.00% - 7.68 99.85 4.67

REC (RGGVY) 4.47 11.50% - 0.32 4.15 0.25 REC (RGGVY) 4.15 11.50% - 0.30 3.86 0.23

JICA Loan 63.34 0.80% 200.00 4.52 258.82 0.64 JICA Loan 258.82 0.80% 18.49 240.33 1.00

World Bank Loan 194.35 1.25% - 13.88 180.47 10.78 World Bank Loan 180.47 0.01 - 12.89 167.58 10.01

Commercial bank for Electrification schemes

110.41 10.60% - 7.89 102.53 5.64 Commercial bank for Electrification schemes

102.53 10.60% - 7.32 95.20 5.24

Total CAPEX Loan (A) 2,610.39 10.76% 611.50 186.46 3,035.44 151.88 Total CAPEX Loan (A) 3,035.44 10.54% 402.50 216.82 3,221.12 164.78

WORKING CAPITAL LOAN (B)

PFC-TFL 49.99 10.25% - - 49.99 2.56 PFC-TFL - 10.25% - - - -

REC-TFL - 12.00% - - - - REC-TFL - 12.00% - - - -




DHBVN Bonds 162.86 9.80% - - 162.86 7.98 DHBVN Bonds - 9.80% - - - -

UDAY Tranche 1 2,756.48 8.21% - - 2,756.48 113.15 UDAY Tranche 1 805.45 8.21% - - 805.45 33.06




Nov-17 Page 63



Principal Repayment

CB Int. 01.10.2018 to 31.03.2019 OB ROI Planned Receipt

Principal Repayment

CB Int.




526.43 8.21% - - 526.43 21.61 State Govt. Loan 31.03.2016

131.61 8.21% - - 131.61 5.40


230.50 8.18% - - 230.50 9.43 State Govt. Loan 15.06.2016

230.50 8.18% - - 230.50 9.43


9.13 8.14% - - 9.13 0.37 State Govt. Loan 30.06.2016

9.13 8.14% - - 9.13 0.37


23.58 8.06% - - 23.58 0.95 State Govt. Loan 04.07.2016

23.58 8.06% - - 23.58 0.95

FRP Bonds 188.19 9.80% - - 188.19 9.22 FRP Bonds - 9.80% - - - -

Cash Credit Limit 350.00 10.55% - - 350.00 18.46 Cash Credit Limit 350.00 10.55% 200.00 - 550.00 23.74

Loan from GoH - 7.26% - - - - Loan from GoH - 7.26% - - - -

OFR 1,759.18 8.21% 708.20 - 2,467.38 86.75 OFR 2,467.38 8.21% 708.20 - 3,175.57 115.82

Total WC Loan (B) 7,909.14 8.49% 708.20 - 8,617.34 350.61 Total WC Loan (B) 5,870.44 4.25% 908.20 - 6,778.64 268.90

Grand Total (A+B) 10519.53 4.53% 1319.70 186.46 11652.77 502.50 Grand Total (A+B) 8,905.88 4.59% 1,310.70 216.82 9,999.76 433.68

Nov-17 Page 64


Table 30: Net Interest & Finance Charges (Rs. In Crores)


Interest on UDAY bonds payable to the State Government 399.94 239.76

Interest on remaining loans

Interest on WC loans including CC/OD limits 174.54 339.18

Interest on CAPEX loans 146.69 184.73

Interest Cost on Consumer Security Deposit 74.81 76.87

Guarantee Fees 3.76 4.01

Interest Cost of Jind Loans 88.79 56.37

Net Interest 888.53 900.92

A prayer has been made in the filing to allow the entire interest cost which is actual

payout on the real loans of the Discom in the Revenue Requirement.

3.16 Depreciation

For FY 2017-18, the Nigam has estimated depreciation charges on the basis of

estimated additions in GFA as per the capital investment plan for FY 2017-18.

The transfer of total CAPEX to fixed asset has been considered as 60%. The

Nigam has considered the Capital Expenditure of Rs 1100 Cr as approved by

Hon’ble Commission for FY 2017-18 and for FY 2018-19 the Nigam proposes a

Capital expenditure of Rs 1300 Cr.

For the purpose of projecting deprecation charges for FY 2017-18 and FY 2018-

19, the licensee has considered the category-wise actual depreciation rates (as a

percentage of opening balance of asset-class-wise GFA for that year). The

following depreciation rates have been used for calculating depreciation:

Table 31: Asset wise Depreciation rate

Types of Assets Rate of Depreciation (%)

Land -

Buildings 3.34%

Plant & Machinery 5.28%

Vehicle 18.00%

Nov-17 Page 65


Types of Assets Rate of Depreciation (%)

Furniture and fixtures 6.33%

The detailed calculation of depreciation for FY 2017–18 is provided in the tables

below:

Table 32: Depreciation for FY 2017–18 (Amount in Crores)

Particulars Accumulated Depreciation ( 1st Apr 2017)

Additions during the year Balance

Depreciation (31st Mar 2018)

Rate of Depreciation

(%)

Depreciation during the

year Total

Land & Land Rights

- - - - -

Buildings & Civil Structure

51.50 3.34% 8.03 8.03 59.53

Plant & Machinery 2,260.67 5.28% 391.05 391.05 2,651.72

Vehicles 12.26 18.00% 3.27 3.27 15.53

Furniture & Fixture 11.73 6.33% 1.35 1.35 13.08

Less: Depreciation on assets contributed by Consumers and grants

- 104.63

Total 2,336.16 3.88% 299.06 403.69 2,739.86

Table 33: Depreciation for FY 2018-19 (Amount in Crores)

Particulars Accumulated Depreciation ( 1st Apr 2018)

Additions during the year Balance

Depreciation (31st Mar 2019)

Rate of depreciation

(%)

Depreciation during the

year Total

Land & Land Rights

- - - -

Buildings & Civil Structure

59.53 3.34 9.42 9.42 68.95

Plant & Machinery 2,651.72 5.28 455.72 455.72 3,107.45

Vehicles 15.53 18.00 3.78 3.78 19.31

Furniture & Fixture 13.08 6.33 1.57 1.57 14.65

Less: Depreciation on assets contributed by Consumers and grants

105.90

Total 2,739.86 4.05% 364.59 470.50 3,210.36

Nov-17 Page 66


3.17 Non-Tariff Income

The Non-Tariff income mainly comprises the following elements:

a) Interest on staff loans & advances;

b) Interest on fixed deposits with banks & company etc.;

c) Delayed payment charges from consumers;

d) Meter Service Rental;

e) Recovery of theft of Power;

f) Interest Income on Provident Fund;

g) Misc. Charges from consumers;

h) Income from staff welfare activities;

i) Miscellaneous receipts;

j) Rent from Residential Building;

The petitioner projects the non-tariff income, in line with the actual figures for

FY 2016-17. The actual figure of NTI for FY 2016-17 is Rs 542.86 Cr. Non-Tariff

Income such as discount for timely payment of Energy Charge and Meter rental

services is escalated at the rate equal to rate of increase in sales and No of

Consumers.

Table 34: Non-Tariff income for FY 2018 and FY 2018-19 (Amt. in Rs. Crores)


Non – Tariff Income 247.47 247.47

The Petitioner prays the Hon’ble Commission to approve non-tariff income for

FY 2017-18 and FY 2018-19 as tabulated above.

Nov-17 Page 67


3.18 Return on Equity

The computation of return on equity for FY 2017-18 and FY 2018-19 is tabulated

below:

Table 35: Return on Equity for FY 2018 and FY 2018-19 (Amt. in Rs. Crores)


Opening Share Capital 2,544.33 3,268.71

Share Capital received under UDAY 724.38 764.38

Closing Share Capital 3,268.71 4,033.09

Average Share Capital 2,906.52 3,650.90

Rate of Return on Equity (RoE) 14.00% 14.00%

Total Return on Equity (RoE) 406.91 511.13

The petitioner requests Hon’ble Commission to approve the computation of

return on equity for FY 2017-18 and FY 2018-19, as tabulated above.

3.19 Interest on Consumer Security Deposit

The petitioner submits that Interest on Security Deposit amount has been

claimed as per the provision of MYT Regulations, 2012. As per assumption

made in Tariff Order, dated 29/05/2014,

“Interest on security deposit shall be calculated at the Bank Rate as on 1st

April of the financial year in which petition is filed.“

Hence, the Petitioner has considered Interest for Security Deposit as below:

Table 36: Interest on Consumer Security Deposit for FY18 & FY19 (Amt. in Rs Crores)

Particulars FY 2017-18

(Projections) FY 2018-19

(Projections)

Opening balance 1,147.17 1,154.63

Receipt during the year 7.46 55.96

Closing balance 1,154.63 1,210.59

Average 1,150.90 1,182.61

Interest rate 6.50% 6.50%

Interest on Consumer Security Deposit 74.81 76.87

Nov-17 Page 68


3.20 Bad and Doubtful Debts

It is hereby submitted that section 64 of the MYT Regulations, 2012 provides for

creation of provision for Bad and Doubtful debts. The relevant extract of the

aforementioned regulations has been given in the below:

“64 BAD AND DOUBTFUL DEBTS

Bad and doubtful debts shall be allowed to the extent the distribution

licensee has actually written off bad debts subject to a maximum of 0.5% of

sales revenue. However, this shall be allowed only if the distribution

licensee submits all relevant data and information to the satisfaction of the

Commission. In case there is any recovery of bad debts already written off,

the recovered bad debts will be treated as other income.”

As per the provision of the MYT Regulation, 2012 the Nigam has estimated a

provision for bad and doubtful debts of Rs 53.84 Cr and Rs 57.76 Cr for FY 2017-

18 and FY 2018-19 respectively. The Hon’ble Commission is requested to

approve the same.

3.21 Revenue Estimation

The Petitioner has projected the revenue from intra-state sales for the FY 2017-

18 based on the sales projected above. The projected sales is distributed

subcategory wise based on the past years sub-category wise distribution and

multiplying the projected and subcategory wise distributed sales of the 1st

Quarter with the Tariff determined by the Hon’ble Commission. The Hon’ble

Commission had notified the Tariff Order dated 11.07.2017 wherein the Hon’ble

Commission had revised the tariff applicable to all the categories except for

Domestic consumers having consumption less than 150 units per month and

AP consumer. Therefore, the licensee has projected the revenue for the period

starting from July’17 to March’17 based on the aforementioned Tariff Order

Nov-17 Page 69


dated 11.07.2017. Similarly, the licensee has projected the revenue for the FY

2018-19. The details of the same have been given as under:

Table 37: Revenue Estimations for FY 2017-18 and FY 2018-19 (In Crs.)

Category FY 2017-18 FY 2018-19

Domestic 2,497.05 2,693.85

Non-Domestic 1,851.46 2,038.37

HT Industry 3,526.81 3,765.08

LT industry 663.48 704.19

Lift irrigation 120.71 128.26

Agriculture 39.06 35.25

Bulk supply 417.77 436.73

Railway traction 132.23 96.07

Street Lighting 66.03 70.37

PWW 426.28 473.16

Total Energy Charge 9,740.87 10,441.31

Fixed Charges 1,136.03 1,226.85

Total Revenue 10,876.91 11,668.16

Collection Efficiency 99% 99%

Revenue Realised 10,768.14 11,551.47

3.22 Revenue from inter-state sales:

Revenue from inter-state sales projected for FY 2017-18 and FY 2018-19 has been

considered at 80% of average variable power purchase cost.

3.23 Agriculture Subsidies:

Agriculture Subsidy for the FY 2017-18 has been taken after escalating the

approved subsidy of FY 2017-18 by 5%.

3.24 Tariff Requirement:

The following table summarizes the estimated Aggregate Revenue

Requirement (ARR) of DHBVN for FY 2017-18 and FY 2018-19.

Nov-17 Page 70


Table 38: Aggregate Revenue Requirement for FY 2017-18 and FY 2018-19 (Amt. in Rs Crores)

Sr. No.

Particulars FY 2017-18 Approved

FY 2017-18 Projected


1 Total Power Purchase Expense 11,925.86 13,841.47 13,803.21

1.1 Power Purchase Expense 11,021.51 12,146.73 12,025.08

1.2 Interstate transmission Charge - 790.39 843.74

1.3 Intrastate trans. charges and SLDC charges

904.36 904.36 934.38

2 Operations and Maintenance Expenses 1,367.00 1,399.16 1,399.52

2.1 Employee Expense 790.12 884.90 820.03

2.2 Administration & General Expense 77.72 83.67 85.18

2.3 Repair & Maintenance Expense 114.16 129.60 151.06

2.4 Terminal Liability 385.00 301.00 343.25

3 Depreciation 288.87 299.06 364.59

4 Total Interest & Finance Charges 343.99 406.23 445.59

4.1 Net Interest on Capex Loans 122.06 146.69 184.73

4.2 Interest on Working Capital (Normative

Basis) 125.91 180.97 179.99

4.3 Interest on Consumer Security Deposits 93.02 74.81 76.87

4.4 Other Interest and Finance charges 3.00 3.76 4.01

5 Return on Equity Capital 173.16 406.91 511.13

6 Other Expenses 53.84 57.76

7 Total Expenditure 14,098.89 16,406.68 16,581.79

8 Interest on Actual Working Loans 888.53 900.92

8.1 Interest on UDAY bonds payable to the State Government

399.94 239.76

Interest on remaining loans

8.2 Interest on WC loans including CC/OD

limits

174.54 339.18

8.3 Interest on CAPEX loans 146.69 184.73

8.5 Interest Cost on Consumer Security

Deposit

74.81 76.87

8.6 Guarantee Fees 3.76 4.01

8.7 Interest Cost of Jind Loans 88.79 56.37

9 Actual Expenditure (Adjusted with Normative interest on Loan)

14,098.88 16,888.98 17,037.12

10 Less: Non-Tariff Income 247.47 247.47 247.47

11 Net Aggregate Revenue Requirement 13,851.42 16,641.51 16,789.65

12 Total Revenue - 11,518.75 12,388.44

12.1 Revenue from Interstate sales 750.61 836.97

Nov-17 Page 71


Sr. No.

Particulars FY 2017-18 Approved



12.2 Revenue from Intrastate sales / Sale of Power

10,768.14 11,551.47

13 Net Gap (5,122.76) (4,401.21)

14 AP-Subsidy 2,620.34 2,751.36

15 GAP After AP Subsidy (2,502.42) (1,649.85)

Nov-17 Page 72


Table 39: Aggregate Revenue Requirement of Wheeling and Retail Supply (Amount in Rs. Crores)

Summary of ARR of DHBVN FY 2017-

18

FY 2017-

18

FY 2018-

19

FY 2018-

19

S.N

o

Particulars Wheeli

ng

Reta

il

Wheeli

ng

Retail Wheeli

ng

Retail

1 Total Power Purchase Expense

- 13,841.47 - 13,803.21

1.1 Power Purchase Expense 0% 100

% - 12,146.73 - 12,025.08

1.2 Interstate transmission Charge 0% 100

% - 790.39 - 843.74

1.3 Intrastate transmission charges and SLDC charges 0% 100

% - 904.36 - 934.38

2 Operations and Maintenance Expenses

695.09 704.07 699.89 699.63

2.1 Employee Expense 48% 52% 424.75 460.15 393.61 426.41

2.2 Administration & General Expense 42% 58% 35.14 48.53 35.77 49.40

2.3 Repair & Maintenance Expense 70% 30% 90.72 38.88 105.74 45.32

2.4 Terminal Liability 48% 52% 144.48 156.52 164.76 178.49

3 Depreciation 82% 18% 245.23 53.83 298.97 65.63

4 Total Interest & Finance Charges

150.50 255.74 184.65 260.94

4.1 Net Interest on Capex Loans 90% 10% 132.02 14.67 166.25 18.47

4.2 Interest on Working Capital(Normative Basis) 10% 90% 18.10 162.87 18.00 161.99

4.3 Interest on Consumer Security Deposits 0% 100

% - 74.81 - 76.87

4.4 Other Interest and Finance charges 10% 90% 0.38 3.39 0.40 3.61

5 Return on Equity Capital 90% 10% 366.22 40.69 460.01 51.11

6 Other Expenses 29% 71% 15.61 38.23 16.75 41.01

7 Total Expenditure 11% 89% 1,472.65 14,934.03 1,660.27 14,921.52

8 Interest on Actual Working Loans

198.73 689.81 230.19 670.74

8.1 Interest on UDAY bonds 10% 90% 39.99 359.95 23.98 215.79

8.2 Interest on 25% remaining WC loans under UDAY including

CC/OD limits

10% 90% 17.45 157.08 33.92 305.26

8.3 Interest on CAPEX loans 90% 10% 132.02 14.67 166.25 18.47

8.4 Interest on Loans taken after 1st Oct 2015 but before MoU 10% 90% - - - -

8.5 Interest Cost on Consumer Security Deposit 0% 100

% - 74.81 - 76.87

8.6 Guarantee Fees 10% 90% 0.38 3.39 0.40 3.61

8.7 Interest Cost of Jind Loans 10% 90% 8.88 79.91 5.64 50.73

9 Actual Expenditure (Adjusted with Normative interest on

Loan)

1,520.88 15,368.10 1,705.81 15,331.32

10 Less: Non-Tariff Income 11% 89% 27.22 220.25 27.22 220.25

11 Net Aggregate Revenue Requirement

1,493.66 15,147.85 1,678.58 15,111.07

3.25 True up of RE subsidy for FY 2016-17

The total agricultural sales approved by the Hon’ble Commission in FY 2016-17 were

9094 MUs and against the same a subsidy of Rs. 5933.54 Crs. for DHBVN and DHBVN

Nov-17 Page 73


was allowed. This amounts to a per unit subsidy of Rs. 6.52/unit. Based on the feeder

data, the actual agricultural sales, following HERC methodology of 16% losses on AP

Feeder data emerges to 4066.68 MUs for DHBVN and 5034.95 MUs for DHBVN.

Therefore, for total sales of 9,101.64 MUs, the eligibility of subsidy emerges to Rs.

5,938.52 Crores (9,101.64 MUs*Rs. 6.52 per unit). Consequently, post true up, the

surplus subsidy emerges to Rs. 241.83 Crores.

Table 40: True up of RE subsidy for FY 2016-17

Particulars 2016-17

Total RE subsidy allowed by HERC in Tariff order for 2016-17 (Rs Crs) 5,933.54

Total Agricultural sales approved by HERC in T.O (Mus) 9,094.00

Approved Per unit Subsidy (Rs./unit) 6.52



Agriculture Sales based on Feeder data minus 16% losses (Mus) 9,101.64

Eligibility of subsidy based on actual sales of 2016-17 (Rs. Crs) 5,938.52

Subsidy Outstanding/(Surplus) (Rs. Crs) 4.98

Nov-17 Page 74


Chapter 4. Recovery of Outstanding Gaps

Recovery of Gaps

The ARR has been prepared on the basis of actual wherein the foreseen expenses

and revenue have been projected. The Hon’ble Commission is requested to

continue with the current levels of tariff and FSA based on which the total gap after

True-up for FY 2016-17 comes at Rs. 2,240.15 Crs; after re-assessment of ARR gap

for FY 2017-18 comes out to be Rs. 1,759.18 Crs and for FY 2018-19 at Rs. 1,416.39

Crs respectively.

The resultant gap after continuation of current levels of tariff will be met through

the OFR as proposed under UDAY.

Nov-17 Page 75


Chapter 5. Additional Surcharge

The Petitioner submits that Regulation 22 of the “Haryana Electricity

Regulatory Commission (Terms and conditions for grant of connectivity and

open access for intra-State transmission and distribution system)

Regulations, 2012 provides as under:

“Additional Surcharge. - (1) An open access consumer, receiving supply

of electricity from a person other than the distribution licensee of his area

of supply, shall pay to the distribution licensee an additional surcharge

in addition to wheeling charges and cross-subsidy surcharge, to meet

out the fixed cost of such distribution licensee arising out of his

obligation to supply as provided under sub-section (4) of Section 42 of

the Act.

Provided that such additional surcharge shall not be levied in case open

access is provided to a person who has established a captive generation

plant for carrying the electricity to the destination of his own use.

(2) This additional surcharge shall become applicable only if the

obligation of the licensee in terms of power purchase commitments has

been and continues to be stranded or there is an unavoidable obligation

and incidence to bear fixed costs consequent to such a contract.

However, the fixed costs related to network assets would be recovered

through wheeling charges.

(3) The distribution licensee shall submit to the Commission, on six

monthly basis the details regarding the quantum of such stranded costs

and the period over which these remained stranded and would be

stranded. The Commission shall scrutinize the statement of calculation

of such stranded fixed costs submitted by the distribution licensee and

determine the amount of additional surcharge.

Nov-17 Page 76


Provided that any additional surcharge so determined shall be applicable

to all the consumers availing open access from the date of determination

of same by the Commission.

(4) The consumers located in the area of supply of a distribution licensee

but availing open access exclusively on inter-State transmission system

shall also pay the additional surcharge.

(5) Additional surcharge determined on per unit basis shall be payable,

on monthly basis, by the open access customers based on the actual

energy drawn during the month through open access”.

Since the Petitioner has a universal obligation to supply power to all the

consumers, they have to enter into long term agreements for purchase of

power from various generating stations for meeting entire demand of the

State. As such, when these Open Access consumers draw power from any

other mode under Open Access i.e. through collective transaction or bilateral

transaction, the fixed cost of such stranded power is still payable by the

Petitioner, while making it a stranded capacity for the petitioner.

In accordance with the Haryana Electricity Regulatory Commission (Terms

and Conditions for grant of connectivity and open access for intra-State

transmission and distribution system) Regulations, 2012, the Nigam hereby

submits the calculation of additional surcharge based on 100% data of all

days in first half of FY 2017-18 i.e. April-17 to September-17. The

methodology for computation of Additional Surcharge is explained below:

In order to ensure that only such power surrendered is taken for calculating

additional surcharge, which corresponds to power stranded because of open

access consumers, the lower quantum of open access power per slot and

surrendered power for corresponding slot is taken as quantum of the

stranded power for slot due to open access.

Nov-17 Page 77


The Discoms have calculated slot wise stranded power due to open access

and also the total open access power availed in that particular time slot.

Further, based on slot-wise quantum eligible for calculation of Additional

Surcharge and slot wise total open access power availed, the corresponding

slot wise units have been calculated for all the days in first half of FY 2017-

18 and thereafter the petitioner has calculated total units in MU, which

corresponds to the stranded power due to Open Access and total Open

Access units availed for the first half of FY 2017-18.

Subsequently, the total Additional Surcharge for first half of FY 2017-18 (in

Rs. Crores) is calculated by multiplying the Units of Power (in MUs)

evaluated above and the per unit effective fixed charge as calculated in the

table below.

Table 41: Approved Per unit fixed cost of power purchase for FY 2017-18

Sr. No. Generating Plants

Estimated Quantum

Fixed Cost

in MU Rs Cr

1 NTPC

2 Singrauli STPS 1326.66 83.82

3 Rihand I 434.17 36.61

4 Rihand II 380.73 33.32

5 Rihand III 374.39 56.69

6 FGTPS Unchhahar I 51.73 6.11

7 FGTPS Unchhahar II 108.19 13.19

8 FGTPS Unchhahar III 69.48 10.65

9 Anta CCGT 33.35 11.88

10 Auraiya CCGT 18.51 14.17

11 Dadri CCGT 40.37 15.73

12 Faridabad CCGT 1213.47 227.86

13 Farakka STPS 85.55 6.26

14 Kahalgaon I 133.92 17.09

15 Kahalgaon II 341.1 51.63

16 Kol Dam HEP 299.78 49.85

17 NHPC -

Nov-17 Page 78



Estimated Quantum

Fixed Cost

in MU Rs Cr

18 Salal I 435.57 95.38

19 Bairasiul 182.18 23.83

20 Tanakpur 24.93 4.53

21 Chamera I 318.68 30.83

22 Chamera II 71.66 8.97

23 Chamera-III 79.42 20.91

24 Dhauliganga 54.37 8.93

25 Dulhasti 104.17 30.47

26 Uri 130.2 12.14

27 Uri-II 55.46 21.86

28 Sewa II 26.24 7.64

29 Parbati-III 51.45 13.61

30 SJVNL HEP 250.43 46.88

31 Rampur HEP (SJVNL) 66.46 15.67

32 THDC -

33 Tehri Stage I HEP 180.08 63.31

34 Koteshwar HEP 43.19 9.76

35 NPCIL -

36 NAPP 180.11 -

37 RAPP (3-4) 308.77 0.02

38 RAPP (5-6) 160.47 0.01

39 HPGCL 17252.66 1,764.23

40 Shared Project -

41 BBMB HEP 2622.38 -

42 DVC -

43 DVC Mejia-B 473.46 125.09

44 Koderma DVC HEP 473.51 70.81

45 DVC Raghunathpur TPP 152.5 23.17

46 UMPP -

47 CGPL Mundra UMPP 2435.73 235.20

48 Sasan UMPP 3088.13 50.57

49 Others -

50 PTC Tala, HEP 51.34 -

51 PTC GMR Kamalanga TPS 2102.41 161.23

52 PTC Baglihar HEP 269.2 -

Nov-17 Page 79



Estimated Quantum

Fixed Cost

in MU Rs Cr

53 PTC Lanco Amarkantak 1840.07 229.09

54 PTC Karchamwangtoo JSW HE 764.46 -

55 IGSTPP, APCPL (Aravali) 1824.94 794.47

56 Pragati Gas Bawana 0 100.44

57 Adani Power Ltd. Mundra TPS 9780.38 1,182.81

58 Teesta III HEP 0 83.88

59 MGSTPS, CLP, Jhajjar 3294 775.09

60 Bhoruka HEP 29.15 -

61 P&R Gogripur HEP 9.72 -

62 Puri Oil Mill HEP 13.64 -

63 Biomass Projects 143.06 -

64 Cogeneration Plants 271.94 -

65 Solar Projects (JNNSM &Siwana) 21.27 -

66 HPGCL Solar 17.5 -

67 SECI Solar 133.16 -

68 PGCIL Transmission 1,401.62

69 Total 54700 8,047.30

70 Avg Fixed Cost of Power Purchase exc. PGCIL Charges 1.21

Finally, the Per Unit Additional Surcharge is determined by dividing the

total additional surcharge with the estimated Open Access Units for second

First half of FY 2017-18 (considering same open access scenario as in First

half of FY 2017-18) in Mus.

The details of the backing down owing to Open Access in MW and MU for

calculation of additional surcharges and Open Access availed is given in the

table below:

Table 42: Details of backing down owing to Open Access and Open Access units.

Row Labels Average of Min

in MW Sum of Min in

MU Average of Total OA

Sum of Total OA in MU

Apr 256.06 184.36 256.06 184.36

May 199.28 148.26 199.28 148.26

Jun 207.86 149.66 207.86 149.66

Jul 178.28 132.64 183.66 136.64

Aug 157.83 117.43 159.25 118.48

Nov-17 Page 80


Row Labels Average of Min

in MW Sum of Min in

MU Average of Total OA

Sum of Total OA in MU

Sep 49.69 35.78 49.74 35.81

Grand Total 174.89 768.12 176.05 773.21

A summary of total additional surcharge that may be allowed to the

Petitioners is summarized below:

Table 43: Calculation of Additional Surcharge for Second half of FY 2016-17.

Particulars Units Amount

Total Units of Power in MUs to be considered for Additional Surcharge

in MU 768.12

Effective Approved Fixed Cost considered for the purpose of Evaluating Additional Surcharge

Rs/ Unit

1.21

Total Additional Surcharge for the FY 2017-18 H1 IN Rs. Crores In Rs

Million 933.22

Open Access Units estimated (considering same open access scenario as in FY 2017-18) in Mus

in MU 773.21

Per Unit Additional Surcharge applicable on the same Quantum of Open Access (Rs./unit)

Rs/ Unit

1.21

The Hon’ble Commission is requested to allow an additional surcharge of Rs

1.21 per unit to be levied on open access consumers which has been

calculated based on details of slot wise surrendered power and slot wise

open access power considering data of all days.

Nov-17 Page 81


Chapter 6. Compliance to Directives issued in last Tariff Order

Sr. No. HERC Directives for FY 2017-18 Submission to Commission Directives

1 Licensee shall have to implement Smart Metering along with

Advance Metering Infrastructure (AMI) facility and have to roll

out the smart metering plan in accordance to timeline specified

in National Tariff Policy, 2016. Smart meters should have

additional feature to get re-configure into pre-paid and post-

paid functions. Additionally, the specification of smart meters

shall be kept in line with the functional requirement of CEA. The

specification of smart meters and list of approved vendors shall

have to displayed on Licensee website. Further, Licensee shall

have to develop necessary infrastructure required for

installation of smart meter to consumer categories like telecom

towers, street lighting, bulk supply and temporary connection.

Haryana Distribution Utilities in consultation with Ministry of Power (GoI) have collaborated

with Energy Efficiency Service Limited under ESCO Model and planned to rolled out Smart

Metering Solution for One million of consumers (5 Lacs for each DISCOM). Under ESCO

arrangement, project will be funded completely by EESL and subsequently will build, operate

and manage the Smart Metering system.

EESL has initiated procurement process and floated NIT for purchase of One-million Meters

having GPRS communication facility. Furthermore, the process of selection of a system

integrator and communication service providers is in advance phase and will be selected

through competitive bidding.

The pay-out of Smart Metering Project will be made to EESL through improvement in billing

efficiency plus pass through of the cost borne by Nigam on account of meter rent and meter

reading.

Nigam is working out on operational and financial parameters of the business model

proposed by the EESL for Smart Metering. Rigorous deliberations have been carried with

EESL and efforts are being made to freeze an appropriate business plan which is by and large

shall be in the favour of Nigam. Once, the terms and conditions of above parameters settled

out, the same will be put in to HERC in form of Petition, for the formal approval of the Project.

Thereafter, Nigam will sign the formal agreement with the EESL.

Nov-17 Page 82



2 Formulate Roadmap for Smart Grid and submit tentative cost

estimates in upcoming ARR Petition.

Smart Grid is being implemented under the Pilot mode in Gurugram City. The Project cost is

of 1608 Crores and will be implemented in phased manner. In the first phase, upgradation of

distribution infrastructure is being carried out to ensure 24x7 power supply, in the identified

area (Sector 1 to Sector 57) of Gurugram. In the subsequent phase, implementation of SCADA

will be carried out. Thereafter, in the final phase, installation of AMI Smart Meters at the

consumers end will be undertaken. Works for upgradation of distribution network for 24x7

power supply is divided into four parts. In the first part DLF and Sector 14 areas will be

covered, whereas in second part Maruti and IDC areas will be taken up, thereafter in third

part Kaadipur areas will be completed and in the last part of the phase first, Sohna Road and

New colony area will be covered. At present, work has been awarded for initial two parts,

which are of amount Rs 250 Crores each. The remaining part of the work will be awarded in

till February 2018. Furthermore, the appointment of consultant for roll out of SCADA is under

process and same will awarded after issuance of work order for all the parts of the first phase

of the project. It is expected that project will tentatively be completed within 3 years.

3 Training program or calendar to be prepared within three

months’ time for upgradation of staff skills pertaining to

RAPDRP, Smart Metering and Smart Grid Technologies.

Further penal of experts on the subject related to organisation

can be formed and services of experts can be utilised for the

training purpose.

Nigam submits that various training programmes pertaining to skillset upgradation of staff

have already been conducted at HPTI, Panchkula. Training programs of Group-C staff of

Nigam (like ALM, LM, SA, ASSA, SSA, JE & JE-I) are conducted on batch-wise merit order.

The nomination of the staff is made from each Circle-Operation. Besides, the senior staff of

Nigam are being sent to various Training Institutes from time to time.

In general training is provided on the organisation related subjects like linemen training,

Metering & Billing, Financial Management, Stores Accounting & Office Administration, Up-

gradation of IT Skills, Operation & Maintenance of Distribution Transformer, Prevention of

failures and repairs, Safety, accident prevention and Disaster Management etc.

Nov-17 Page 83



During the last financial year, training of 882 numbers of employees has been conducted at

HPTI, Panchkula. Moreover, Nigam has sent 52 numbers of Class-I & II employees to the

prominent institutes of India under the specialised training program.

However, in regard to skillset up-gradation of staff, pertaining to rapid technological changes

and implementation of various schemes such as R-APDRP, Smart Metering and Smart Grid

technologies, Nigam is imparting the regular training to field staff under RAPDRP Wing.

Whereas, training in respect to GIS, MDAS and other modules of RAPDRP, the officials of the

Nigam are being given special with the help ITIA as well as TPDDL experts.

Furthermore, it is submitted that at corporate level, team of subject matter experts have been

created under the R-APDRP wing. These teams are designated to RAPDRP offices to provide

online support to carry out the day in day out operational activities.

Nigam submits that a formal training program for the staff, covering the latest technological

trends in the domain of Smart Metering and Smart Grid will be formulated in consultation

with the agencies engaged in pilot projects and successful commissioning of the same.

4 Development to centralised billing system for consistency in

billing. Integration of Adhar No. with billing system and

submission of compliance report within three months.

Nigam submits that the centralised billing system has already been in place. In RAPDRP areas

billing is being carried out by M/s HCL, whereby in Non RAPDRP billing is done by M/s

HATRON. The matter is under consideration of management to shift the Non-RAPDRP area

billing to the R-APDRP platform.

Furthermore, following initiatives have been taken to reduce the human error and to increase

the accuracy in billing system: -

• New connection/load extension cases are being processed through online portal.

Nov-17 Page 84



• Implementation of Meter reading of consumers via Hand held device has been

implemented and this will help in capturing all the billing parameters (kWh, kVAh,

MDI) and hence will help the Nigam in analysing the accurate meter details

immediately after the current billing cycle.

It is further submitted, that in order to incorporate the KYC details of consumers into the

billing system the KYC details collection campaign is being run either by Nigam’s own or

outsourced resources. Moreover, Nigam has appointed M/s Pragya-ware for integration

KYC matrix in billing system and further authentication of consumer AADHAR number and

other contact details from UIDAI.

5 Discoms to take up the matter of clearing pending electricity bill

dues of government department with the State Government.

Progress on the same to be update to Commission.

Nigam submits that the matter of outstanding electricity bill dues of Govt. Departments has

been taken up with the worthy APSCM of State Government in a meeting held on date 14th

March 2017. It was instructed to Govt Departments to clear their pending electricity bills dues

outstanding with DISCOMs. In this line, State Govt. Departments have submitted a request

specifying that the matter of surcharge waiver has been taken up with the Hon’ble Chief

Minister, Government of Haryana. The proposal of one-time surcharge wavier has been

approved by Chief Minister and same has been forwarded to the Finance Department for

making necessary provisions in the budget of govt. Departments for clearing the outstanding

electricity dues.

Presently, the outstanding amount pending with the Govt. Departments is Rs. 875.38 Crores

(till September, 2017), out of which Rs. 453.57 Crores correspond to surcharge. The details of

defaulting amount corresponding to various Govt. departments is provided as under: -

Nov-17 Page 85



(Figures are in Rs. Lac)

Govt. Department No. of

Defaulters Principal Amount

Surcharge Amount

Total

Irrigation 903 2472.3 32737.76 35210.06

P.W.W. 4936 9635.51 2831.38 12466.88

MC's/M. Corp. 2661 22118.86 7447.5 29566.36

Panchayat 1355 1236.07 555.49 1791.56

Others 3330 6717.95 1785.2 8503.15

Total 13185 42180.69 45357.32 87538.01

6 Launching of promotional campaign for Roof Top Solar PV

installations through local TV and Newspapers. Also, collection

of feedback from consumers to understand the

bottleneck/difficulties in overall implementation process.

Based on feedback being received from the consumers/ channel partners approved by MNRE

a simplified procedure/guideline were formulated and already stand circulated vide Sales

Circular D-18/2016. To disseminate proper awareness among the concerned Nigam officers

regular training program is being organised, so that the applicants do not come across of any

difficulty while applying for Net Metering connection. The underlying benefits of the scheme

are being propagated in various interactive meeting held with RWA/Industrial Association.

7 Exploration of possibilities to appointment Gram Panchayat as

retail supply franchisee (under section 13 of EA, 2003) for

improvement of service to the consumers and providing single

point supply connection to such at bulk supply rate.

It is submitted that the Nigam is exploring the possibility of appointment of Gram Panchayats

as retail supply Franchisee. A proposal in this regard was sent to the Hon’ble Commission.

While approving the proposal, the Hon’ble Commission stated that the energy to such

Panchayats Institutions may be made available by the Discoms at the bulk supply rate (cost

of power at Discoms periphery). However, as both these rate i.e. bulk supply rates and cost

of power at Discom’s periphery are different, a reference has been made to the Commission

for seeking clarification regarding the rates to be applicable for supply of energy in case of

such Gram Panchayats/retail supply franchisees.

Nov-17 Page 86



8 Analysis of Domestic & Non-Domestic consumption pattern of

past three years and identification of cases warranting load

extension. Also, issuance of notice to consumers for voluntary

enhancement of load within a set time frame and allowing

security deposit submission in instalments to such consumers.

The requisite logic in billing software is being worked out and appropriate action will be

taken thereof within two months.

9 Payment of interest on security deposit to consumer in next

billing cycle. Also, detail of unclaimed security deposit to be

furnished by the Nigam, where consumer has discontinued the

receiving of supply. Further, appropriate action on the same

should be taken as per the accounting practise within six

months.

Nigam submits that the payment of interest on Advance Consumption Deposit (ACD) is

already functional in R-APDRP areas. However, in Non-RAPDRP areas, payment of ACD has

been made to all consumers falling under Domestic and Non-Domestic category. It is further

submitted that on submission of legitimate proof regarding the discontinuation of electricity

supply by the consumer, Nigam credits the ACD amount to the consumer. Nigam has also

directed to all circle officers to integrate the unpaid ACD details into the billing system where

consumer have relinquished the electricity supply connection from the Nigam.

10 Release of AP Tube-well connection under Tatkal Scheme is still

under pendency, a status notes on the same to be submitted

within 30 days.

Nigam is striving hard to clear the backlog /pendency of release of AP connection under

Tatkal Scheme. AP Tube-well supply connection work is now being executed through

empanelled contractors of 11 kV works under EOI-09. It is submitted that Nigam will clear

the pendency of release of AP Tube-well connections under Tatkal Scheme within two

months of time. Nigam further ensures that the fresh AP Tube-well connection under the

Tatkal Scheme will be released in time bound manner as specified by the Hon’ble

Commission in relevant Regulations.

Applications received for AP Tube-well connection under Tatkal Scheme are of 9494 in

numbers as on 30th September, 2017. Out of the total application received, Nigam has released

7540 Nos of connections and the remaining 1954 applications are under the process. Circle-

wise Progress of Tatkal Scheme uptill September, 2017 is as under:

Nov-17 Page 87



Circle Application

Received (Sep’17)

Connections

Released (Sep’17)

Balance

Connection

Faridabad 219 180 39

Palwal 555 364 191

Gurugram-1 3 2 1

Gurugram-2 99 67 32

Narnaul 1192 1013 179

Rewari 426 308 118

Bhiwani 1712 1430 282

Hisar 598 529 69

Fatehabad 1354 1286 68

Sirsa 2205 1538 667

Jind 1131 823 308

DHBVN 9494 7540 1954

11 Appointment of adequate manpower (positioning of Chairman

& Members) and strengthening of CGRF office facilities within

two months.

It is submitted by the Nigam that appointed adequate manpower in Consumer Grievance

Redressal Forum (CGRF). Nigam has deployed one Superintending Engineer and Chief

Accounts Officer as the Chairman and Members of the Forum, respectively at corporate office

Hisar. Additionally, one member and secretary of the forum has also been posted at HERC,

Panchkula. Nigam has provided adequate manpower and facilities to ensure that CGRF

should be strengthen appropriately.

12 Discoms are direct that post lying vacant for more than two

years shall not be filled without prior approval of the

Commission. However, a report to be submitted by the Nigam

Nigam submits that no recruitment has been made without any prior from approval from the

State Government. However, appointment of staff for sanctioned 511 Nos of non-technical

Nov-17 Page 88



regarding the abolishment of non-technical post lying vacant for

more than two years in compliance to the direction issued in

post three Tariff Orders of the Commission. Compliance report

to be submitted within 45 days to the Commission, failure in

doing so will result in disallowance of such expenditure in

subsequent ARR.

posts is made in accordance with the provisions specified under Part II of the Outsourcing

Policy.

Currently, no such non-technical posts are lying vacant from last two years. Moreover,

requisitions for the appointment of 761 Nos. of non-technical posts have been sent for

recruitment to HSSC-Panchkula, with the approval from the Govt of Haryana.

It is further submitted that total of 380 Nos. of non-technical posts was abolished by the

Nigam, on account of creation of 181 Nos. IT cadre posts, as approved by HBPE, Finance

Dept. of Haryana.

13 To promote the digital payment, Nigam has to bear the

transaction charges (Merchant Discount Rate) levied by the

bank on online transactions made through payment gateway.

Further the consumers in urban areas, those having bill of

amount Rs 10,000 and above can make the payment of electricity

bill either through above payment modes or from RTGS/NEFT

and the bank authorised by the Nigam.

In compliance of the directions issued by the Hon’ble Commission, an instruction has been

issued by the Nigam that the transaction charges (MDR) on the payment made through

payment gate-way, net-banking, e-wallet, POS/swipe machine etc. or by way of credit &

debit card, net banking, is being borne by the Nigam with effect from 1st November 2017.

14 Facilities like downloading of bill from website and providing

the bill details through SMS & e-mail shall be extended without

any charges, to consumers having load more than 10kW and

above. Further in order to encourage environmental

consciousness among the consumers, facility for exercising the

option of “No Hard copy of Bills” shall be made available on

website.

Nigam has provided the facilities of downloading electricity bills from Nigam’s website and

sending bill details through SMS in RAPDRP areas, to all the consumers having load 10 kW

and above. Moreover, facility of sending bill alerts through SMS is also available in Non-

RAPDRP areas. However, possibility of mailing and downloading electricity bills from

website of the Nigam, are being explored for consumers in Non-RAPDRP areas.

Furthermore, the awareness among the consumers to download electricity from e-mail or

website is being carried out by the Nigam through the KYC details collection campaign, run

Nov-17 Page 89



either by its own or outsourced resources. Option of “No Hard Copy of Bills” shall be

provided to the consumers, once substantial awareness spread out among the consumers.

15 To run an extensive campaign for voluntary give-up of AP

Subsidy through electricity bill/SMS/e-mail, for the consumer

having annual income more than 20 lakhs annually.

Nigam submits that at present the consumer data collection is under the process through KYC

details integration in the billing system and Nigam will subsequently use the same to run its

campaign for Voluntary Give-Up Subsidy of AP Consumer.

16 In view of heavy expenditure, shortage of technical staff and

over staffed non-technical staff, Discoms have to take up actions

for re-structuring of staff in compliance to the directives issued

in Tariff Order dated 1st August, 2016. Discom, to take up the

matter of restructuring with the State Govt and to submit the

status of the same to the Commission.

It is submitted that the Nigam has formulated a Committee for restructuring of the staff.

Meeting of the committee members are being held on regular basis. Nigam is trying to devise

some cost-effective approach for staff-restructuring and will subsequently present the

detailed proposal to the State Government for in principle approval.

17 Compliance to the directives and issuance of sale relevant

circulars in shall be done within the time limit specified for the

purpose.

Nigam submits that the relevant sales circulars have been issued and uploaded on the

website, immediately after the publication of the HERC Tariff Order dated 11th July 2017.

18 Discom may explore for the alternatives like providing of

distribution franchisee to other companies to reduce the line

losses and financial losses, considering the interest of public in

large.

Nigam submits that it is making its best efforts to reduce down the line losses and financial

losses. Nigam has made significant technical loss reduction over the past years. Technical

losses of Nigam have been reduced by 13.03% from FY 2002-03 to FY 2016-17. Nigam have

initiated loss reduction schemes across the license area. In urban areas works have been

carried out under feeder sanitisation scheme and in rural area the same is carried under

Mhara Goan Jagmag Goan (MGJG) scheme. Nigam have done substantial loss reduction of

13.80% in the loss level of 57 Nos RDS feeders undertaken in MGJG. Moreover, the current

line loss level of Nigam is 19.75% which will be aligned with UDAY loss trajectory by the end

of the financial year. Further, in the direction of minimising the technical and commercial

Nov-17 Page 90



losses, Nigam is in process of implementing the Centralised billing system across the licensee

area, installation of energy efficient equipment like LED Bulbs & 4 Star rating AP Motors

under DSM initiatives, roll out of Smart Metering and Smart Grid project under technological

changes. Rigorous efforts are being made by the Nigam to safeguard public interest and

enhance consumer satisfaction, simultaneously.

19 Circle wise details of the consumer having double supply

connection along with the suitable justification shall be

provided to the Commission

Nigam submits that in general there are no such case of double connection supply. However,

double supply connections were issued earlier to building of state importance considering

the power supply condition during that phase. So far, double supply connections have been

eliminated from the system, due to robust distribution network and supply conditions. It is

further submitted that Nigam will take the appropriate action, if any such cases comes into

notice at any point of time.

20 Identification of DSM Plan and submission of same to

commission for consideration.

Nigam submits that it has implemented ToU/ToD tariff vide Sales Circular No. D- 29/2017

dated 17.08.2017 which will encourage the consumer to opt for power from Nigam at lower

tariff thereby contributing to flattening of load curve. Nigam has also taken various other

initiatives for Demand Side Management which are given here under: -

• Nigam has made mandatory to install 4 star rated motors and transformers. • Rebate on electricity bill is also provided to consumer those has installed Solar Water

Heater. • As per Sales Circular No. D-10/2017, installation of Solar photovoltaic power plant

mandatory for specified category of building/area. • Nigam has run the campaign with the name of UJALA, under which more than 66.96

lacs florescent lamps have been replaced with LED lamps leading to reduction of peak demand of more than 300 MW.

• Nigam is also implementing Smart Metering in four towns.

Nov-17 Page 91



21 The distribution licensees are directed to explain the reason of

under achievement even after re-fixing of their distribution loss

level/AT&C loss trajectory envisaged under UDAY scheme.

To achieve the targeted distribution loss levels/ AT&C loss trajectory set under UDAY

scheme, the NIGAM has undertaken various initiatives like Urban Feeder Sanitization, Rural

Domestic Feeder Sanitization under MGJG Scheme, theft detection, MRBD through Hand

Held Device etc. A YoY comparison of targeted Distribution loss and Loss level actually

achieved is as under:

AT&C Loss (%) FY 2015-16 FY 2016-17 FY 2017-18

Projection 25.22 % 22.48 % 18.76%

Actual 26.45 % 21.14% -

Gap 1.23 % -1.34% -

From the above table, it is evident that the loss target of FY 2016-17 has been comprehensively

achieved by the Nigam, AT&C losses during the year were brought down to the level of

21.14% against the projection of 22.48%. Further, in order to bring down the loss level of RDS

feeders, MGJG scheme is under implementation in phased manner and the Distribution losses

of the feeders covered and completed under MGJG scheme have been reduced significantly.

The scheme is being implemented in phased manner even with the stiff resistance from the

consumers of Rural Areas. Support of district administration is also being taken for

implementation of the aforementioned scheme. Overall impact on the achievement of AT&C

loss target under MGJG Scheme will be visible after completion of work on all Rural Domestic

Feeders.

Following steps have been taken by the Nigam to reduce technical and commercial losses

with specific focus on long term improvement in the power quality/reliability.

Nov-17 Page 92



• Discoms has constituted theft detection teams to reduce commercial leakages through theft/pilferage. There has been significant increase in number of theft cases booked in theft, when compared year on year basis:

Financial Year Theft

Detected (Nos)

Assessment Amount (Rs. Lac)

Realization Amount (Rs. Lac)

2014-15 16,273 4,719.11 2,547.11

2015-16 24,904 8,533.78 3,916.21

2016-17 41,275 10,105.50 4,240.92

2017-18 (H1) 39,440 12,047.47 4,670.93

• The outstanding arrears are being recovered by launching arrear recovery scheme and by assigning arrear recovery targets to the subdivision.

• Feeder Sanitization activities are being carried out geographically as: 1. Urban Feeder Sanitization 2. Mahra Gaon Jagmag Gaon Scheme.

In both the Schemes, NIGAM has focused on the following: -

➢ Accurate meter reading via replacement of defective, electromechanical and old version meters.

➢ Minimizing occurrence of theft of energy via relocation of meter from inside of the consumer premises to outside on the poles.

➢ Preventive measures to eliminate direct theft of energy by replacing ACSR, bare conductor with LT AB Cables in theft prone areas.

➢ Release of new connection in un-electrified household, unauthorized colonies to bring them in the billing net.

• Meter Reading of consumers through Hand Held device - DISCOMs have introduced Meter Reading for all consumers through Hand Held Device. The meter reading of the consumers will be downloaded directly to Hand held device without any manual/human intervention. The loss of units due to malpractice or human error will be mitigated by this

Nov-17 Page 93



process which will result in improvement of billing efficiency. At present, the work for Meter reading activity has been allotted to firms. All the subdivisions have been rolled out under MRBD Scheme.

• IEC (Information, Education & Communication Campaign) for MGJG scheme of UHBVN/DHBVN for a period of 3 months as a pilot project launched w.e.f. 06.07.2017

With the above initiatives DISCOM will strive hard to achieve the milestones set in the

upcoming year.

Outcome/ Impact of MGJG Scheme

Under MGJG Scheme 56, 80, 128, 142 & 25 (total 431) RDS feeders were selected under Phase

I, II, III, IV & IV-A respectively. Work on 77 feeders has been completed till 31st March 2017.

Analysis of losses on 57 feeders has been carried out & the comparison is attached as

Annexure-I. From this analysis, there is increase in units billed by 270.90 LUs and reduction

in losses by 13.80% as compared to the figures of corresponding period of previous year.

Further efforts are also being made to reduce the losses by way of sanitization of completed

feeder.

21 The Commission also directs the distribution licensees to bring

down the total number of rural feeders with line losses above

50% as on 31.03.2017 to half and to bring down the losses of all

urban feeders below 25% by the time of next ARR/APR filing.

The distribution licensees are further directed to file report on

the status of losses on each of these feeders and also

prominently display them on their website (Page-222).

The status of RDS feeders having distribution losses more than 50% in rural area and Urban

feeders having distribution losses more than 25% in urban area for FY 2015-16 and FY 2016-

17 is tabulated as under:

RDS Feeders FY 16 FY 17 FY18

(Sept’17)

Total no. of RDS Feeder 812 887 926

Total no. of RDS Feeder having losses

above 50% 539 562 561

Percentage of total feeder having losses

above 50% 66.37% 63.36% 60.58%

Nov-17 Page 94



Urban Feeders FY 16 FY 17 FY18

(Sept’17)

Total no. of Urban Feeder 718 728 734

Total no. of Urban Feeder having losses

above 25% 206 159 156

Percentage of Total Feeder having losses

above 25% 28.83% 21.84% 21.25%

The above status i.e. list of feeders for FY 2016-17 Annexure-II is available on the website of

DHBVN. Also, from the above table, it can be observed that although the number of feeders

having losses above 50% in Rural areas has slightly been increased during FY 2017-18, but

same will be eventually be improved after completion of ongoing loss reduction program

under MGJG scheme. Whereas, the total nos. of urban feeders having losses more than 25%

have been declined prominently during the FY 2016-17 and the percentage of such feeders

has reduced from 28.83% to 21.84%. The percentage of Urban Feeders having losses above

25% is likely to be decreased during FY 2017-18 due to ongoing loss reduction programme.

Further, in order to reduce feeder losses, Nigam has taken various Loss Reduction Program

(LRP). In the urban areas, LRP is taken under Urban Feeder Sanitization and in Rural area

same is under Mhara Gaon Jagmag Gaon (MGJG) Scheme. The activities involve the

following: -

• Meter Replacement (Tampered/Defective/Faulty/Old Version/ Electromechanical)

Meter Relocation (Meters lying inside the premises to outside/on poles)

• AB Cabling (ACSR replacement in theft prone areas)

• New Connections (Unauthorized colonies/ connections)

As these are on-going activities, the result will be visible at the culmination of the activities

Nov-17 Page 95



22 The HERC vide its Regulation (Standards of Performance for

Distribution Licensee) Regulations 2004, has specified the

failure rate of distribution transformers as maximum 5% for

urban area DTs and maximum 10% for rural area DTs.

The Commission again directs the licensees to examine the

cause of damage of DTs in the areas where it is above the norms

and endeavour to bring down the distribution transformer

damage rate below the prescribed limits by ensuring proper

maintenance and protection (Page-227).

The percentage DT failure rate (excluding warranty period) during

FY 2016-17 vis-à-vis during FY 2017-18 (up to September 2017) is as under:

Area FY 2016-17 FY 2017-18 (Sept,17)

Rural 6.67% 3.85%

Urban 3.26% 2.56%

Overall 6.31% 3.71%

Furthermore, the Nigam submits that the proper maintenance of the DT as per the

maintenance schedule, load balancing, and installation of proper fuse will not only further

reduce the failure rate but also will help in betterment of the efficiency of the DT. Moreover,

the SDOs of different operation circles under the jurisdiction of DHBVN has been given

special power to purchase petty equipment upto Rs. 1 lac per month for the repair and

maintenance work for HT, LT lines and DTs. Thus, the aggregate transformer damage rate in

FY 2017-18 is expected to be well below the figures of 2016-17.

23 “All the EM meters exist in the urban areas should be replaced

by December, 2017. 50% of EM meters exist in rural areas should

be replaced by December, 2017. The licensee should endeavour

to replace the EM in a systematic manner by taking a specific

area/circle at a time” (Page-232)

The distribution licensees are also directed to submit the

detailed action plan for replacement of defective meters and

electromechanical meters consistent with the time lines set by

the Commission in the matter. (Page-232)

It is submitted that at the beginning of FY 2017-18, the count of electromechanical meters

present in the system were 3,29,005. During the first half of the financial year of FY 2017-18

Nigam replaced 43,790 electromechanical meters whose details are provided below:

EM meters Replaced

Single Phase Three Phase G. Total Rural Urban Total Rural Urban Total

FY 2017-18 H1 26,922 12,225 39,147 857 3,786 4,643 43,790

It is pertinent to mention that, the Nigam is implementing the MRBD project in which one of

the deliverables is the survey of the meters installed in the premises. After the reconciliation

of the data thus obtain from the survey the final count of EM meters may get impacted.

Nov-17 Page 96



24 The Discoms are directed to take up the issue of any unpaid

subsidy vis-a-vis that determined by the Commission in its tariff

Order or FSA Order under intimation to the Commission.

Hence, the Commission decides that the Discoms shall enforce

all the measures including disconnection of AP consumers in

case of non-payment of bills on the same lines as is done in the

case of other consumers. However, if for any policy reasons, the

Discoms fail to do so then the cost of such additional working

capital shall be borne by the State Government. (Page-247)

The issue of unpaid subsidy vis-à-vis that determined by the Commission including FSA

subsidy for AP consumers, has been taken up with the State Govt. in the supplementary

budget.

A.P Subsidy payable for FY 2017-18 amounting to Rs. 7398.12 Cr. (6550.86 Cr. i.e. subsidy

required to keep the tariff at current level + 847.26 Cr. i.e. arrear for RE subsidy for FY 2015-

16) determined in the current year Tariff Order dated 11.07.2017 has been taken up with the

State Government.

Instructions for disconnection of any consumer on non-payment of electricity dues are

already exists.

Nov-17 Page 97



25 Companies, during the public hearing on their Annual

Performance Review petition for FY 2016-17, intimated the

following details with regard to defective energy meters.

Meter

category

No. of defective meters (end

March, 2016)

No. of defective meters

(end March, 2017)

Rural Urban Total Rural Urban Total

1 Phase 98097 15835 113932 104101 9133 113234

3 Phase 46287 4970 51257 49753 3826 53579

Total 144384 20805 165189 153854 12959 166813

Accordingly, the licensees are, therefore, once again directed to

submit a detailed report within two months from the date of

issue of this Order, indicating the detailed reason for not

meeting with the targets assigned along with future course of

action to achieve the targets, failure to do so shall attract penal

action as per the Electricity Act, 2003. The licensees are also

directed to intimate the average time taken for replacement of

defective meter along with area wise and age wise defective

meters pending for replacement. (Page-229-230)

Replacement of defective meters is a continuous process for Discom. DHBVN has replaced

1,36,864 defective meters during FY 2016-17. Due to extensive survey of consumer premises

under MRBD project, more number of defective meter are coming to notice of the NIGAM

and are being replaced. Instruction has been issued to all subdivision for early replacement

of defective meters. The status of defective meters ending FY 2016-17 (i.e. 3/2017) and during

FY 2017-18 (upto 9/2017) is as under:

Status of Defective meters ending FY 2016-17 (upto 03/2016)

No, of defective meter 1Φ 3Φ


Ending Mar’16 98097 15835 113932 46327 4930 51257

Add during FY17 67452 54166 121618 5406 11464 16870

Replaced during FY17 61448 60868 122316 1940 12608 14548

Balance at the end of FY17 104101 9133 113234 49793 3786 53579

Status of Defective meters during FY 2016-17 (upto 09/2017)

No, of defective meter 1Φ 3Φ


Ending Mar’17 104101 9133 113234 49793 3786 53579

Add during Apr’17 to Sep’17

42254 24547 66801 2285 6955 9240

Replaced during Apr’17 to Sep’17

36293 25149 61442 3647 7389 11036

Balance at the end of Sep’17 110062 8531 118593 48413 3352 51783

Nov-17 Page 98



26 The Commission is of the considered view that a scientific methodology needs to be developed to calculate voltage wise and category wise losses so as the COS of respective category could be calculated precisely.

Accordingly, licensees are directed to finalize the methodology

for Cost of supply (CoS)/voltage wise and category wise cost of

services and submit the proposal to the Commission for its

approval within three months from the date of issue of this

Order.

In reference to the Nigam submits that a presentation was held on 22.12.2015, wherein the Consultant M/s Feedback Infra Pvt. Ltd on behalf of the Utility presented the methodology followed in Cost of Supply Study to the Hon’ble Commission and it was requested before the Hon’ble Commission to provide the in-principle approval of the methodology adopted for the CoS Study.

It is pertinent to mention that the Hon’ble Commission is yet to accord approval of the methodology proposed by the Nigam. Once the methodology adopted for calculation of Voltage Wise cost of supply is approved by the Hon’ble Commission the final report of voltage wise cost of Supply will be submitted to HERC for approval and compliance of directive.

Furthermore, the Nigam submits that a communication has been made with HERC vide memo no. 74 SE/RA-560 dated 17.11.2017 in this regard.

27 The Commission had directed the Discom to purchase

renewable energy or RECs to meet the RPO targets set for the

FY 2016-17 and also to make up for the shortfall of RPO

compliance carried forward for the previous years, on actual

basis. In view of Haryana Government’s mandate to promote

RE energy especially roof top solar and Waste to Energy,

Discom was directed to meet the maximum RPO targets from

these sources (Page-67).

The Commission directs the Discoms to purchase renewable

energy or RECs to meet with the RPO targets set for the FY 2017-

18 and also to make up for the shortfall of RPO compliance

carried forward for the previous years, on actual basis (Page-

188).

I) RPO Target for FY 2017-18

As per HERC order dated 11.7.2017, the total Solar RPO Target is 867.11 MUs including

backlog of 377 MUs. Total Non-solar RPO target is 1498.25 MUs including backlog of 420

MUs. In order to meet the said RPO target, the action plan is detailed as below: -

II) Action Plan to Purchase Solar Power

HPPC has following proposals in hand to purchase solar power:

1. HPPC is in the process of floating tender to purchase 300 MW solar power through tariff

based competitive bidding. Bidding documents have been submitted in HERC for its

approval. However, the NIT is being revised as per Guidelines for Tariff Based

Competitive Bidding Process for Procurement of Power from Grid Connected Solar PV

Power Projects issued by MoP, GoI on 3.8.2017

2. SCPP has allowed HPGCL to install 52.8 MW solar power plants at their own plants.

Nov-17 Page 99


The Discoms and other obligated entities are directed to provide requisite information regarding RPO obligation to the State Agency on monthly basis by 10th of every month for the previous month to enable the State Agency to submit quarterly report to the Commission (Page-189)

3. HAREDA envisage 1600 MW solar power through Rooftop by FY 2021-22.

4. SECI has proposed 250 MW @ Rs. 4.50 per unit fixed for 25 years under VGF scheme.

HPPC had filed a petition in HERC to seek approval to purchase this power. The Hon’ble

Commission vide letter dated 21.3.2017 had sought reasonability of tariff of Rs.

4.50/KWh. HPPC has requested SECI to clarify the same vide letter dated 30.3.2017

followed by reminders dated 25.4.2017 & 21.6.2017 but no reply was received from SECI.

Now, MNRE vide its D.O letter dated 3.7.2017 intimated that SECI will bring out the

State specific tenders based on the demand and agreed benchmark tariff under Batch IV

of Phase II of JNNSM.

Accordingly, SCPP in its meeting held on 26.9.2017 approved to purchase 250 MW solar

power at a ceiling tariff of Rs 2.44/ KWh at Haryana periphery. The same was conveyed

to SECI along with HERC vide letter dated 18.10.2017.

5. NTPC has proposed 353 MW bundled power with 200 MW thermal power of Sangrauli

TPP. HPPC had filed a petition in HERC to seek approval to purchase this power. HERC

vide its interim Order dated 25.5.2017 has directed as under:

“The Commission directs HPPC to carefully examine the terms & conditions of existing PPA

signed with NTPC, Singrauli and work out the possibility of drawing power under the terms of

the existing PPA only. Accordingly, HPPC is directed to review its proposal and may also

consider to withdraw the present proposal”.

It is pertinent to point out the Bulk Power Supply Agreement (BPSA) signed between

NTPC and erstwhile HSEB dated 31.1.1994 states as under:

12. EFFECTIVE DATE AND DURATION OF AGREEMENT

In case Bulk Power Customer (S) continue to get power from the NTPC Station(s) even after

expiry of this Agreement without further renewal or formal extension thereof, then all the

provisions of this agreement shall continue to operate till this agreement is formally renewed,

extended or replaced.

Nov-17 Page 100



In view of the HERC order, HPPC has requested NTPC to revise their proposal of

bundled power with tariff aligned to prevailing market conditions but reply is still

awaited.

III) Action Plan to Purchase Non- Solar Power

1. The HPPC has signed the PPA for 25 MW & 7 MW with M/s Narayangarh Sugar Mill &

M/s GEMCO Energy Ltd respectively for supply of non-solar RE power.

2. M/s K2 Power Gen Pvt. Ltd. has offered 2 MW Capacity Grid Connected from Biomass

Gasifier Power Plant proposed in State of Haryana on self-identified basis. Accordingly,

after approval of SCPP, the petition no. PRO-16 of 2017 was filed with HERC for source

approval and the case was heard by HERC on 18.07.2017. The decision of the Hon’ble

Commission is awaited.

3. NIT for procurement of 200 MW wind power for long term from ISTS (Inter-State

transmission system) connected wind power projects through tariff based competitive

bidding process along with PPA has been prepared on the basis of RFP floated by SECI

on the guidelines issued by MNRE/GOI from ISTS connected wind power projects in

India. The draft NIT is under approval from HERC before publishing.

4. M/s RSL Distilleries Pvt. Ltd. offered to sell 3.5 MW power to be generated from 5.5 MW

biomass cogeneration power plants proposed at Karnal. The proposal of firm is under

evaluation in HAREDA.

5. M/s Mor Bio Energy Private Limited., Village Ludana, Tehsil Saffidon, Distt. Jind has

offered to sell 1.2 MW capacity from Bio-gas power project to be setup on self-identified

basis.

Nov-17 Page 101



6. Some other non-solar RE based projects like M/s Saraswati Sugar Mill Yamuna Nagar.

M/s KML Distilleries Karnal have requested HAREDA for approval of its DPR of

biomass based project.

7. The Urban Local Body, Haryana has floated the RfP to select the developer to set up

waste to energy plant for at least 10 MW at Bhandwari, Gurgaon.

8. HAREDA is in the process to float the RfP for procurement of 50 MW power from

paddy straw biomass based power in 6 districts namely Ambala, Kurukshetra, Kaithal,

Karnal, Jind and Fatehabad.

9. HPPC has given 400 MW wind power requirement in IInd phase of 1000 MW wind

scheme of Solar Energy Corporation of India (SECI) subject to the approval of HERC.

10. HPPC is also in the process to float the NIT for Procurement of upto 737 Mus RE Non-

Solar power from 15.11.2017 to 31.03.2018 on short-term basis through Tariff based

competitive bidding process for FY 2017-18.

Purchase of REC’s:-

It is pertinent to point out that purchase of Renewable power is more beneficial and in the

interest of consumers than purchase of REC. The same has been acknowledged by the Hon’ble

Commission in its Order dated 20.11.2013 which is reproduced here under:

The Commission is of the view that it is always preferable to purchase renewable energy because of fact that such generation projects as per the statutes has to be encouraged, rather than to purchase REC wherein the amount paid for purchase of the same goes to the generator without even getting the benefit of power availability. Further because of its distributed nature, RE generation is considered advantageous in terms of reduced cost of transmission network and reduced transmission losses. This advantage becomes considerably enhanced when such RE is generated and consumed locally. Therefore, the Discoms in Haryana should prefer to purchase RE generated in Haryana.

Nov-17 Page 102


Chapter 7. Prayer

The Nigam respectfully prays that the Hon’ble Commission may:

• Take the accompanying filing of DHBVN on record and accept the petition

regarding true up of expenses and revenue for FY 2016-17, Re-estimation of

Revenue Requirement / Gap for FY 2017-18 and projected Revenue

Requirement for FY 2018-19;

• Allow filing of any additional / supplementary submissions during the

course of these proceedings;

• Allow return on equity as proposed;

• Allow the entire fixed charges of power purchase as the power is procured

from the sources whose PPAs have been duly approved by the Hon’ble

Commission and also the energy charges of power procurement from these

sources as proposed in the filing;

• Allow the Annual Revenue Requirement of the Nigam for the FY 2018-19

including the actual interest on all the loans which is real expenditure borne

by the utility;

• Allow True-Up of FY 2016-17 along with the holding cost and the revised

expenses as projected for FY 2017-18 in the Annual Revenue Requirement of

FY 2018-19;

• To continue the current levels of Tariff to meet the expenses, the gap being

funded through operational financing as proposed under UDAY scheme;

• To allow Additional Surcharge of Rs 1.21 per unit to be recovered from Open

Access Consumers

Nov-17 Page 103


• Condone any inadvertent omissions/errors/shortcomings and permit

DHBVN to add/change/modify/alter this filing and make further

submissions as may be required during the course of these proceedings;

• Pass such Order, as the Hon’ble Commission may deem fit and appropriate

keeping in view the facts and circumstances of the case submitted by the

Petitioner.

Sr. No.Name of District

Name of 11KV feeder

No. of villages

Month of Completion

Present Supply Hours

Period (On Completion)

Units

received Units billed Difference

Cumula-tive

losses

Increase/Decrease in

losses

08/15 to 03/16 31.96 20.22 11.75 36.75

08/16 to 03/17 30.93 21.82 9.10 29.43

02/15 to 03/16 115.47 54.97 60.50 52.39

02/16 to 03/17 109.40 56.04 53.36 48.78

147.43 75.19 72.24 49.00

140.33 77.86 62.46 44.51

12/15 to 03/16 7.77 3.28 4.49 57.75

12/16 to 03/17 6.03 2.32 3.71 61.50

11/15 to 03/16 24.50 9.36 15.14 61.80

11/16 to 03/17 25.92 13.29 12.63 48.72

32.28 12.64 19.63 60.82

31.96 15.62 16.34 51.13

02/15 to 03/16 83.25 67.71 15.54 18.67

02/16 to 03/17 102.06 82.21 19.85 19.45

03/15 to 03/16 131.84 84.95 46.89 35.57

03/16 to 03/17 123.72 91.49 32.23 26.05

07/15 to 03/16 110.3 66.64 43.66 39.58

07/16 to 03/17 119.54 91.53 28.01 23.43

325.39 219.30 106.09 32.60

345.32 265.23 80.09 23.19

07/15 to 03/16 35.72 23.31 12.41 34.74

07/16 to 03/17 59.89 46.68 13.21 22.06

35.72 23.31 12.41 34.74

59.89 46.68 13.21 22.06

08/15 to 03/16 17.43 5.95 11.48 65.84

08/16 to 03/17 14.48 11.21 3.27 22.59

08/15 to 03/16 29.64 15.79 13.85 46.72

08/16 to 03/17 18.47 14.82 3.66 19.79

08/15 to 03/16 73.54 20.58 52.96 72.01

08/16 to 03/17 55.77 38.93 16.84 30.20

120.61 42.33 78.28 64.90

88.73 64.96 23.77 26.79

02/15 to 03/16 37.80 13.83 23.97 63.42

02/16 to 03/17 32.02 19.34 12.68 39.60

01/15 to 03/16 55.80 34.99 20.81 37.30

01/16 to 03/17 64.84 44.47 20.37 31.41

08/15 to 03/16 58.75 25.02 33.73 57.41

08/16 to 03/17 52.95 36.20 16.75 31.63

152.35 73.84 78.51 51.53

149.81 100.01 49.80 33.24

10/15 to 03/16 22.94 10.46 12.49 54.43

10/16 to 03/17 24.76 21.45 3.31 13.37

09/15 to 03/16 7.64 4.78 2.86 37.43

09/16 to 03/17 5.36 4.45 0.91 16.98

10/15 to 03/16 8.90 4.16 4.74 53.26

10/16 to 03/17 6.27 4.16 2.11 33.65

09/15 to 03/16 6.99 2.11 4.88 69.82

09/16 to 03/17 10.67 5.97 4.71 44.10

46.47 21.50 24.96 53.72

47.07 36.03 11.04 23.45

Shah Pur 4 29.02.2016 18:00 Hrs -3.62

Total Before completion of work

Comparision of T&D Losses before and after completion of work of MGJG feeders (Mar-17)

Phase-I1

Faridabad

Fatehpur 1 01.08.2016 15:00 Hrs -7.32

2

Atali 3 27.11.2016 15:00 Hrs -13.08


Total After completion of work

Phase-II3

Faridabad

Sotai 1 20.12.16 15:00 Hrs 3.75

4


Phase-I5

Gurgaon

Bar Gujjar 2 05.08.2015 24:00 Hrs 0.78

6 Dhana 3 14.03.2016 18:00 Hrs -9.52

7 Manesar 1 24.07.2016 15:00 Hrs -16.15



Phase-II8 Gurgaon IBP 1 05.07.2016 15:00 Hrs -12.69



Phase-I9

Mohindergarh

Seka DS 1 20.08.2016 15:00 Hrs

11 Akoli DS 10 20.08.2016 15:00 Hrs -41.81

-43.25

10 Girdharpur 7 20.08.2016 15:00 Hrs -26.93



Phase-I12

Rewari

Khushpura 3 16.02.2016 18:00 Hrs -23.82

14 Ahrod 8 18.08.2016 15:00 Hrs -25.77

13 Ram Garh 7 28.01.2016 18:00 Hrs -5.89

16 Dhawana 1 27.09.2016 24:00 Hrs -20.46



Phase-II15

Rewari

Bhawari 10 16.10.16 15:00 Hrs -41.06

18 Murlipur 2 29.09.2016 15:00 Hrs -25.72

17 Khol 1 03.10.2016 15:00 Hrs -19.61




Name of 11KV feeder

No. of villages

Month of Completion



Units


Cumula-tive

losses


losses


06/15 to 03/16 42.42 17.60 24.82 58.51

06/16 to 03/17 26.18 13.88 12.30 46.99

06/15 to 03/16 60.33 34.46 25.87 42.88

06/16 to 03/17 59.93 40.95 18.98 31.67

102.75 52.06 50.69 49.33

86.11 54.83 31.28 36.32

05/15 to 03/16 22.98 13.31 9.67 42.08

05/16 to 03/17 23.73 18.10 5.63 23.73

05/15 to 03/16 90.63 20.40 70.23 77.49

05/16 to 03/17 91.48 31.65 59.83 65.40

05/15 to 03/16 37.97 22.96 15.01 39.53

05/16 to 03/17 38.21 24.85 13.36 34.96

04/15 to 03/16 25.17 13.78 11.39 45.25

04/16 to 03/17 25.12 14.65 10.47 41.68

176.75 70.45 106.30 60.14

178.54 89.25 89.29 50.01

03/15 to 03/16 14.16 8.97 5.19 36.67

03/16 to 03/17 16.19 9.96 6.23 38.49

03/15 to 03/16 26.85 17.07 9.78 36.41

03/16 to 03/17 44.96 36.37 8.59 19.10

09/15 to 03/16 23.15 13.61 9.54 41.21

09/16 to 03/17 22.52 16.94 5.58 24.78

09/15 to 03/16 38.66 11.27 27.39 70.85

09/16 to 03/17 30.49 22.36 8.13 26.66

102.82 50.92 51.90 50.47

114.16 85.63 28.53 24.99

12/15 to 03/16 1.91 1.25 0.66 34.71

12/16 to 03/17 3.04 2.63 0.41 13.42

09/15 to 03/16 12.73 6.06 6.66 52.35

09/16 to 03/17 13.39 7.80 5.59 41.76

12/15 to 03/16 19.96 14.77 5.19 26.01

12/16 to 03/17 17.57 15.53 2.03 11.58

12/15 to 03/16 15.17 3.56 11.61 76.54

12/16 to 03/17 9.37 7.87 1.50 16.02

09/15 to 03/16 21.27 8.00 13.27 62.39

09/16 to 03/17 15.96 11.25 4.71 29.51

08/15 to 03/16 34.86 8.24 26.62 76.36

08/16 to 03/17 34.02 10.76 23.26 68.37

105.90 41.88 64.02 60.45

93.34 55.84 37.50 40.18

20 Baliyali 1 16.06.2016 15:00 Hrs -11.22

Phase-I19

Bhiwani

New Haluwas 1 16.06.2016 15:00 Hrs -11.52

22 New TibbaLine 5 02.05.2016 18:00 Hrs -12.09



Phase-I21

Hisar

Telanwali 4 02.05.2016 18:00 Hrs -18.35

24 Chirod 2 03.04.2016 18:00 Hrs -3.57

23 Nagthala 1 02.05.2016 18:00 Hrs -4.57

26 Gramin DS 6 29.03.2016 18:00 Hrs -17.31



Phase-I25

Fatehabad

Gadali DS 2 29.03.2016 18:00 Hrs 1.82

28 Buwan 6 06.09.2016 15:00 Hrs -44.18

27Sadhanwas

RDS2 06.09.2016 15:00 Hrs -16.43

30 Bharpur 3 06.09.2016 15:00 Hrs -10.59



Phase-II29

Fatehabad

Bisla 5 13.12.2016 15:00 Hrs -21.29

32 Baliyala 4 13.12.2016 15:00 Hrs -60.52

31 Matana-II 5 13.12.2016 15:00 Hrs -14.43

34 Gajuwala DS 5 23.08.2016 15:00 Hrs -7.99

33Lakhuwali

Dhani DS5 06.09.2016 15:00 Hrs -32.88




Name of 11KV feeder

No. of villages

Month of Completion



Units


Cumula-tive

losses


losses


02/15 to 03/16 37.62 32.01 5.61 14.91

02/16 to 03/17 44.56 34.30 10.26 23.03

02/15 to 03/16 32.12 23.75 8.37 26.06

02/16 to 03/17 35.09 29.69 5.40 15.39

02/15 to 03/16 5.55 4.67 0.88 15.86

02/16 to 03/17 6.25 5.31 0.94 15.04

05/15 to 03/16 9.50 6.82 2.68 28.21

05/16 to 03/17 9.90 8.41 1.49 15.05

03/15 to 03/16 10.93 9.89 1.04 9.50

03/16 to 03/17 14.81 12.01 2.80 18.92

04/15 to 03/16 36.83 27.12 9.71 26.36

04/16 to 03/17 42.26 32.69 9.57 22.65

06/15 to 03/16 34.14 25.89 8.25 24.16

06/16 to 03/17 44.73 35.92 8.81 19.70

06/15 to 03/16 26.91 18.15 8.76 32.55

06/16 to 03/17 50.77 33.74 17.03 33.54

06/15 to 03/16 23.10 17.96 5.14 22.25

06/16 to 03/17 26.07 20.43 5.64 21.63

05/15 to 03/16 2.75 2.54 0.21 7.64

05/16 to 03/17 2.64 2.34 0.30 11.36

05/15 to 03/16 14.45 12.43 2.02 13.99

05/16 to 03/17 16.42 15.24 1.18 7.19

233.89 181.23 52.67 22.52

293.50 230.08 63.43 21.61

09/15 to 03/16 19.69 17.51 2.18 11.07

09/16 to 03/17 20.43 18.41 2.02 9.89

04/15 to 03/16 22.19 17.95 4.24 19.11

04/16 to 03/17 21.18 17.55 3.63 17.14

09/15 to 03/16 19.84 14.37 5.47 27.57

09/16 to 03/17 18.76 16.95 1.81 9.65

08/15 to 03/16 22.62 9.28 13.34 58.97

08/16 to 03/17 20.09 13.81 6.28 31.26

08/15 to 03/16 31.82 18.17 13.65 42.90

08/16 to 03/17 30.87 22.34 8.53 27.63

06/15 to 03/16 7.71 5.94 1.77 22.96

06/16 to 03/17 11.55 8.54 3.01 26.06

09/15 to 03/16 13.11 9.48 3.63 27.69

09/16 to 03/17 12.16 13.20 -1.04 -8.55

05/15 to 03/16 48.38 36.80 11.58 23.94

05/16 to 03/17 41.07 30.64 10.43 25.40

05/15 to 03/16 17.09 13.56 3.53 20.66

05/16 to 03/17 18.01 14.13 3.88 21.54

09/15 to 03/16 5.57 3.93 1.64 29.44

09/16 to 03/17 5.03 4.80 0.23 4.57

12/15 to 03/16 5.21 2.76 2.45 46.94

12/16 to 03/17 2.88 3.21 -0.33 -11.46

193.54 132.24 61.30 31.67

181.60 145.17 36.43 20.06

07/15 to 03/16 25.34 11.24 14.10 55.64

07/16 to 03/17 22.95 11.84 11.11 48.41

25.34 11.24 14.10 55.64

22.95 11.84 11.11 48.41

1801.23 1008.13 793.11 44.03

1833.30 1279.02 554.27 30.23

32.07 270.90 238.83 -13.80

Phase-I35

Sirsa

Talwara 2 18.11.2015 18:00 Hrs 8.12

37 Khatrawan 1 03.11.2015 21:00 Hrs -0.82

36 Bijuwali 5 03.11.2015 24:00 Hrs -10.67

39 Motiwala 2 01.03.2016 18:00 Hrs 9.42

38Kanwarpura

DS2 17.05.2016 24:00 Hrs -13.16

41 Shekhukhera 8 08.06.2016 15:00 Hrs -4.46

40 Bakrianwali 3 25.04.2016 18:00 Hrs -3.72

43 Chak Jalu 3 02.06.2016 15:00 Hrs -0.62

42 Masita 5 07.06.2016 15:00 Hrs 0.99

45 Bansudhar 3 17.05.2016 24:00 Hrs -6.80

44 Ranga 1 11.05.2016 24:00 Hrs 3.73

47Kelnia-

Domestic1 11.04.2016 24:00 Hrs -1.97



Phase-II46

Sirsa

Village II DS 4 04.09.2016 15:00 Hrs -1.18

49 Hanjira-DS 3 30.08.2016 15:00 Hrs -27.72

48Chakkan RDF

RDS4 29.09.2016 15:00 Hrs -17.93

51 Nanuana-RDS 2 14.06.2016 15:00 Hrs 3.10

50 Kutana-DS 4 30.08.2016 15:00 Hrs -15.27

53 Phoolkan-RDF 2 30.05.2016 15:00 Hrs 1.46

52Abootgarh-

RDS4 21.09.2016 15:00 Hrs -36.24

55 Pana RDS 2 05.09.2016 24:00 Hrs -24.87

54Handi Khera

RDF2 30.05.2016 15:00 Hrs 0.89

-7.23



Total Before completion of work (DHBVN as whole

Total After completion of work (DHBVN as whole)



Phase-I57 Jind Malikpur DS 2 24.07.2016 15:00 Hrs

56 Sakta Khera 1 04.12.2016 15:00 Hrs -58.40


Name of 11KV feeder

No. of villages

Month of Completion



Units


Cumula-tive

losses


losses

08/15 to 03/16 31.96 20.22 11.75 36.75

08/16 to 03/17 30.93 21.82 9.10 29.43

02/15 to 03/16 115.47 54.97 60.50 52.39

02/16 to 03/17 109.40 56.04 53.36 48.78

147.43 75.19 72.24 49.00

140.33 77.86 62.46 44.51

12/15 to 03/16 7.77 3.28 4.49 57.75

12/16 to 03/17 6.03 2.32 3.71 61.50

11/15 to 03/16 24.50 9.36 15.14 61.80

11/16 to 03/17 25.92 13.29 12.63 48.72

32.28 12.64 19.63 60.82

31.96 15.62 16.34 51.13

02/15 to 03/16 83.25 67.71 15.54 18.67

02/16 to 03/17 102.06 82.21 19.85 19.45

03/15 to 03/16 131.84 84.95 46.89 35.57

03/16 to 03/17 123.72 91.49 32.23 26.05

07/15 to 03/16 110.3 66.64 43.66 39.58

07/16 to 03/17 119.54 91.53 28.01 23.43

325.39 219.30 106.09 32.60

345.32 265.23 80.09 23.19

07/15 to 03/16 35.72 23.31 12.41 34.74

07/16 to 03/17 59.89 46.68 13.21 22.06

35.72 23.31 12.41 34.74

59.89 46.68 13.21 22.06

08/15 to 03/16 17.43 5.95 11.48 65.84

08/16 to 03/17 14.48 11.21 3.27 22.59

08/15 to 03/16 29.64 15.79 13.85 46.72

08/16 to 03/17 18.47 14.82 3.66 19.79

08/15 to 03/16 73.54 20.58 52.96 72.01

08/16 to 03/17 55.77 38.93 16.84 30.20

120.61 42.33 78.28 64.90

88.73 64.96 23.77 26.79

02/15 to 03/16 37.80 13.83 23.97 63.42

02/16 to 03/17 32.02 19.34 12.68 39.60

01/15 to 03/16 55.80 34.99 20.81 37.30

01/16 to 03/17 64.84 44.47 20.37 31.41

08/15 to 03/16 58.75 25.02 33.73 57.41

08/16 to 03/17 52.95 36.20 16.75 31.63

152.35 73.84 78.51 51.53

149.81 100.01 49.80 33.24

10/15 to 03/16 22.94 10.46 12.49 54.43

10/16 to 03/17 24.76 21.45 3.31 13.37

09/15 to 03/16 7.64 4.78 2.86 37.43

09/16 to 03/17 5.36 4.45 0.91 16.98

10/15 to 03/16 8.90 4.16 4.74 53.26

10/16 to 03/17 6.27 4.16 2.11 33.65

09/15 to 03/16 6.99 2.11 4.88 69.82

09/16 to 03/17 10.67 5.97 4.71 44.10

46.47 21.50 24.96 53.72

47.07 36.03 11.04 23.45

Shah Pur 4 29.02.2016 18:00 Hrs -3.62



Phase-I1

Faridabad

Fatehpur 1 01.08.2016 15:00 Hrs -7.32

2

Atali 3 27.11.2016 15:00 Hrs -13.08



Phase-II3

Faridabad

Sotai 1 20.12.16 15:00 Hrs 3.75

4


Phase-I5

Gurgaon

Bar Gujjar 2 05.08.2015 24:00 Hrs 0.78

6 Dhana 3 14.03.2016 18:00 Hrs -9.52

7 Manesar 1 24.07.2016 15:00 Hrs -16.15



Phase-II8 Gurgaon IBP 1 05.07.2016 15:00 Hrs -12.69



Phase-I9

Mohindergarh

Seka DS 1 20.08.2016 15:00 Hrs

11 Akoli DS 10 20.08.2016 15:00 Hrs -41.81

-43.25

10 Girdharpur 7 20.08.2016 15:00 Hrs -26.93



Phase-I12

Rewari

Khushpura 3 16.02.2016 18:00 Hrs -23.82

14 Ahrod 8 18.08.2016 15:00 Hrs -25.77

13 Ram Garh 7 28.01.2016 18:00 Hrs -5.89

16 Dhawana 1 27.09.2016 24:00 Hrs -20.46



Phase-II15

Rewari

Bhawari 10 16.10.16 15:00 Hrs -41.06

18 Murlipur 2 29.09.2016 15:00 Hrs -25.72

17 Khol 1 03.10.2016 15:00 Hrs -19.61




Name of 11KV feeder

No. of villages

Month of Completion



Units


Cumula-tive

losses


losses


06/15 to 03/16 42.42 17.60 24.82 58.51

06/16 to 03/17 26.18 13.88 12.30 46.99

06/15 to 03/16 60.33 34.46 25.87 42.88

06/16 to 03/17 59.93 40.95 18.98 31.67

102.75 52.06 50.69 49.33

86.11 54.83 31.28 36.32

05/15 to 03/16 22.98 13.31 9.67 42.08

05/16 to 03/17 23.73 18.10 5.63 23.73

05/15 to 03/16 90.63 20.40 70.23 77.49

05/16 to 03/17 91.48 31.65 59.83 65.40

05/15 to 03/16 37.97 22.96 15.01 39.53

05/16 to 03/17 38.21 24.85 13.36 34.96

04/15 to 03/16 25.17 13.78 11.39 45.25

04/16 to 03/17 25.12 14.65 10.47 41.68

176.75 70.45 106.30 60.14

178.54 89.25 89.29 50.01

03/15 to 03/16 14.16 8.97 5.19 36.67

03/16 to 03/17 16.19 9.96 6.23 38.49

03/15 to 03/16 26.85 17.07 9.78 36.41

03/16 to 03/17 44.96 36.37 8.59 19.10

09/15 to 03/16 23.15 13.61 9.54 41.21

09/16 to 03/17 22.52 16.94 5.58 24.78

09/15 to 03/16 38.66 11.27 27.39 70.85

09/16 to 03/17 30.49 22.36 8.13 26.66

102.82 50.92 51.90 50.47

114.16 85.63 28.53 24.99

12/15 to 03/16 1.91 1.25 0.66 34.71

12/16 to 03/17 3.04 2.63 0.41 13.42

09/15 to 03/16 12.73 6.06 6.66 52.35

09/16 to 03/17 13.39 7.80 5.59 41.76

12/15 to 03/16 19.96 14.77 5.19 26.01

12/16 to 03/17 17.57 15.53 2.03 11.58

12/15 to 03/16 15.17 3.56 11.61 76.54

12/16 to 03/17 9.37 7.87 1.50 16.02

09/15 to 03/16 21.27 8.00 13.27 62.39

09/16 to 03/17 15.96 11.25 4.71 29.51

08/15 to 03/16 34.86 8.24 26.62 76.36

08/16 to 03/17 34.02 10.76 23.26 68.37

105.90 41.88 64.02 60.45

93.34 55.84 37.50 40.18

20 Baliyali 1 16.06.2016 15:00 Hrs -11.22

Phase-I19

Bhiwani

New Haluwas 1 16.06.2016 15:00 Hrs -11.52

22 New TibbaLine 5 02.05.2016 18:00 Hrs -12.09



Phase-I21

Hisar

Telanwali 4 02.05.2016 18:00 Hrs -18.35

24 Chirod 2 03.04.2016 18:00 Hrs -3.57

23 Nagthala 1 02.05.2016 18:00 Hrs -4.57

26 Gramin DS 6 29.03.2016 18:00 Hrs -17.31



Phase-I25

Fatehabad

Gadali DS 2 29.03.2016 18:00 Hrs 1.82

28 Buwan 6 06.09.2016 15:00 Hrs -44.18

27Sadhanwas

RDS2 06.09.2016 15:00 Hrs -16.43

30 Bharpur 3 06.09.2016 15:00 Hrs -10.59



Phase-II29

Fatehabad

Bisla 5 13.12.2016 15:00 Hrs -21.29

32 Baliyala 4 13.12.2016 15:00 Hrs -60.52

31 Matana-II 5 13.12.2016 15:00 Hrs -14.43

34 Gajuwala DS 5 23.08.2016 15:00 Hrs -7.99

33Lakhuwali

Dhani DS5 06.09.2016 15:00 Hrs -32.88




Name of 11KV feeder

No. of villages

Month of Completion



Units


Cumula-tive

losses


losses


02/15 to 03/16 37.62 32.01 5.61 14.91

02/16 to 03/17 44.56 34.30 10.26 23.03

02/15 to 03/16 32.12 23.75 8.37 26.06

02/16 to 03/17 35.09 29.69 5.40 15.39

02/15 to 03/16 5.55 4.67 0.88 15.86

02/16 to 03/17 6.25 5.31 0.94 15.04

05/15 to 03/16 9.50 6.82 2.68 28.21

05/16 to 03/17 9.90 8.41 1.49 15.05

03/15 to 03/16 10.93 9.89 1.04 9.50

03/16 to 03/17 14.81 12.01 2.80 18.92

04/15 to 03/16 36.83 27.12 9.71 26.36

04/16 to 03/17 42.26 32.69 9.57 22.65

06/15 to 03/16 34.14 25.89 8.25 24.16

06/16 to 03/17 44.73 35.92 8.81 19.70

06/15 to 03/16 26.91 18.15 8.76 32.55

06/16 to 03/17 50.77 33.74 17.03 33.54

06/15 to 03/16 23.10 17.96 5.14 22.25

06/16 to 03/17 26.07 20.43 5.64 21.63

05/15 to 03/16 2.75 2.54 0.21 7.64

05/16 to 03/17 2.64 2.34 0.30 11.36

05/15 to 03/16 14.45 12.43 2.02 13.99

05/16 to 03/17 16.42 15.24 1.18 7.19

233.89 181.23 52.67 22.52

293.50 230.08 63.43 21.61

09/15 to 03/16 19.69 17.51 2.18 11.07

09/16 to 03/17 20.43 18.41 2.02 9.89

04/15 to 03/16 22.19 17.95 4.24 19.11

04/16 to 03/17 21.18 17.55 3.63 17.14

09/15 to 03/16 19.84 14.37 5.47 27.57

09/16 to 03/17 18.76 16.95 1.81 9.65

08/15 to 03/16 22.62 9.28 13.34 58.97

08/16 to 03/17 20.09 13.81 6.28 31.26

08/15 to 03/16 31.82 18.17 13.65 42.90

08/16 to 03/17 30.87 22.34 8.53 27.63

06/15 to 03/16 7.71 5.94 1.77 22.96

06/16 to 03/17 11.55 8.54 3.01 26.06

09/15 to 03/16 13.11 9.48 3.63 27.69

09/16 to 03/17 12.16 13.20 -1.04 -8.55

05/15 to 03/16 48.38 36.80 11.58 23.94

05/16 to 03/17 41.07 30.64 10.43 25.40

05/15 to 03/16 17.09 13.56 3.53 20.66

05/16 to 03/17 18.01 14.13 3.88 21.54

09/15 to 03/16 5.57 3.93 1.64 29.44

09/16 to 03/17 5.03 4.80 0.23 4.57

12/15 to 03/16 5.21 2.76 2.45 46.94

12/16 to 03/17 2.88 3.21 -0.33 -11.46

193.54 132.24 61.30 31.67

181.60 145.17 36.43 20.06

07/15 to 03/16 25.34 11.24 14.10 55.64

07/16 to 03/17 22.95 11.84 11.11 48.41

25.34 11.24 14.10 55.64

22.95 11.84 11.11 48.41

1801.23 1008.13 793.11 44.03

1833.30 1279.02 554.27 30.23

32.07 270.90 238.83 -13.80

Phase-I35

Sirsa

Talwara 2 18.11.2015 18:00 Hrs 8.12

37 Khatrawan 1 03.11.2015 21:00 Hrs -0.82

36 Bijuwali 5 03.11.2015 24:00 Hrs -10.67

39 Motiwala 2 01.03.2016 18:00 Hrs 9.42

38Kanwarpura

DS2 17.05.2016 24:00 Hrs -13.16

41 Shekhukhera 8 08.06.2016 15:00 Hrs -4.46

40 Bakrianwali 3 25.04.2016 18:00 Hrs -3.72

43 Chak Jalu 3 02.06.2016 15:00 Hrs -0.62

42 Masita 5 07.06.2016 15:00 Hrs 0.99

45 Bansudhar 3 17.05.2016 24:00 Hrs -6.80

44 Ranga 1 11.05.2016 24:00 Hrs 3.73

47Kelnia-

Domestic1 11.04.2016 24:00 Hrs -1.97



Phase-II46

Sirsa

Village II DS 4 04.09.2016 15:00 Hrs -1.18

49 Hanjira-DS 3 30.08.2016 15:00 Hrs -27.72

48Chakkan RDF

RDS4 29.09.2016 15:00 Hrs -17.93

51 Nanuana-RDS 2 14.06.2016 15:00 Hrs 3.10

50 Kutana-DS 4 30.08.2016 15:00 Hrs -15.27

53 Phoolkan-RDF 2 30.05.2016 15:00 Hrs 1.46

52Abootgarh-

RDS4 21.09.2016 15:00 Hrs -36.24

55 Pana RDS 2 05.09.2016 24:00 Hrs -24.87

54Handi Khera

RDF2 30.05.2016 15:00 Hrs 0.89

-7.23



Total Before completion of work (DHBVN as whole

Total After completion of work (DHBVN as whole)



Phase-I57 Jind Malikpur DS 2 24.07.2016 15:00 Hrs

56 Sakta Khera 1 04.12.2016 15:00 Hrs -58.40

UNIT

RECEIVEDUNIT SOLD DIFF.

% LINE

LOSSES

HSR 1 33 KV TOHANA CITY-III Tohana (U) HD741D 4.87 1.35 3.52 72.31 TOHANA CITY TOHANA URBAN

HSR 2 132 KV NARNAUND. NARNAUND (U) HB071H 178.16 75.88 102.28 57.41 HANSI NARNAUND URBAN

HSR 3 132 KV UKLANA CITY-II UKLANA (U) HB131H 90.06 39.50 50.56 56.14 TOHANA UKLANA URBAN

HSR 4 132 KV POLYSTEEL SATROD KHURD (U) HB031B 136.07 71.43 64.63 47.50 HISAR-II SATROD URBAN

HSR 5 132 KV UKLANA CITY-I UKLANA (U) H132A 219.69 115.51 104.19 47.42 TOHANA UKLANA URBAN

HSR 6 132 KV TOHANA CITY-IV Tohana (U) HB111B 158.78 97.71 61.06 38.46 TOHANA CITY TOHANA URBAN

HSR 7 132 KV ARYA NAGAR TULSI VIHAR (U) HB181I 71.05 44.00 27.05 38.07 HISAR-II SATROD URBAN

HSR 8 220 KV BHUNA BHUNA-II (U) HA041F 110.20 68.26 41.94 38.06 TOHANA BHUNA URBAN

HSR 9 132 KV TOHANA CITY-I Tohana (U) HB112A 187.17 116.51 70.66 37.75 TOHANA CITY TOHANA URBAN

HSR 10 132 KV POLYSTEEL SURYA NAGAR (U) HB031H 49.66 31.32 18.35 36.94 HISAR-II SATROD URBAN

HSR 11 220 KV FATEHABAD POLICE LINE (U) HA021H 13.15 8.91 4.24 32.22 FATEHABAD S/U FATEHABAD URBAN

HSR 12 33 KV RATIA CITY-2 Ratia (U) HD721B 131.11 91.34 39.77 30.33 FATEHABAD CITY RATIA URBAN

HSR 13 132 KV HANSI T-1C HIGHWAY (U) HB063C 135.66 95.92 39.74 29.30 HANSI CITY HANSI URBAN

HSR 14 33 KV RATIA CITY-4 Ratia (U) HD722B 89.43 63.62 25.81 28.86 FATEHABAD CITY RATIA URBAN

HSR 15 132 KV HANSI T-1A-1B HANSI TOWN (U) HB061D 174.48 125.09 49.39 28.31 HANSI CITY HANSI URBAN

HSR 16 33 KV RATIA CITY-1 Ratia (U) HD722A 126.36 91.06 35.29 27.93 FATEHABAD CITY RATIA URBAN

HSR 17 132 KV TOHANA CITY-III Tohana (U) HB111E 114.98 83.08 31.90 27.74 TOHANA CITY TOHANA URBAN

HSR 18 132 KV BEER TALWANDI JUGLAN (U) HB014C 143.89 104.52 39.37 27.36 HISAR-I CITY HISAR URBAN

HSR 19 33 KV HTM SHIV NAGAR (U) HD302B 165.35 120.77 44.58 26.96 HISAR-I CITY HISAR URBAN

HSR 20 33 KV BARWALA MC FEEDER (U) HD042B 143.07 104.86 38.21 26.71 HISAR-II BARWALA URBAN

HSR 21 132 KV ADAMPUR ADAMPUR (U) HB051F 109.61 80.38 29.22 26.66 HISAR-II ADAMPUR URBAN

HSR 22 132 KV ARYA NAGAR CHANDAN NAGAR (U) HB181F 59.58 43.90 15.68 26.32 HISAR-I CIVIL LINE URBAN

HSR 23 33 KV SECTOR-14, HISAR BSF (U) HD731F 180.34 134.08 46.26 25.65 HISAR-I CITY HISAR URBAN

HSR 24 220 KV INDUSTRIAL AREA VINOD NAGAR (U) HA011A 154.60 115.63 38.97 25.21 HISAR-I CITY HISAR URBAN

BWN 1 132KV CH. DADRI II. CHIRIYA ROAD (U) (132 KV

CH-DADRI-II)BB131G 42.36 6.52 35.84 84.61 Dadri City Dadri URBAN

BWN 2 33 KV RD-0 Ghikara BYPass (U) BD132C 3.37 0.53 2.83 84.15 Dadri City Dadri URBAN

BWN 3 33 KV S/Stn. Bawani Khera Bawani Khera (MU) BD022A 139.56 71.06 68.50 49.08 City BWN B/Khera MIXED URBAN

BWN 4 132KV CH. DADRI II. DADRI URBAN (U) BB131F 189.50 98.61 90.89 47.96 Dadri City Dadri URBAN

BWN 5 220 S/Stn. Bhiwani Anaj Mandi (U) BA011E 89.86 48.77 41.08 45.72 City BWN S/U-II URBAN

BWN 6 132KV CH. DADRI -I GHIKARA ROAD (U) BB122F 126.00 69.55 56.45 44.80 Dadri City Dadri URBAN

BWN 7 132KV CH. DADRI -I Bus Stand Road (U) BB121C 78.36 43.39 34.97 44.63 Dadri City Dadri URBAN

BWN 8 132KV CH. DADRI -I DADRI (U) BB122D 189.18 105.32 83.86 44.33 Dadri City Dadri URBAN

BWN 9 220 S/Stn. Bhiwani Haluwas (MU) BA011B 115.91 64.79 51.12 44.10 City BWN S/U-II MIXED URBAN

BWN 10 33 KV Ghasola Hira Chowk (U) BD491E 74.09 43.52 30.56 41.25 DADRI City Dadri URBAN

BWN 11 132KV CH. DADRI -I RAWALDHI (MU) BB121A 193.59 116.53 77.05 39.80 Dadri City Dadri MIXED URBAN

BWN 12 132 KV I/A BWN Hanuman Gate (U) BB103B 121.51 83.14 38.37 31.58 City BWN City BWN URBAN

BWN 13 132 Kv S/Stn Haluwas(Bhiwani) Kanu Ram Hospital (U) BB141J 116.42 80.60 35.81 30.76 City BWN City BWN URBAN

BWN 14 132 Kv S/Stn Haluwas(Bhiwani) Jain Chowk (U) BB141K 163.54 116.93 46.61 28.50 City BWN City BWN URBAN

BWN 15 220 S/Stn. Bhiwani Lajpat Nagar (MU) BA011K 37.80 27.23 10.58 27.98 City BWN S/U-II MIXED URBAN

BWN 16 220 S/Stn. Bhiwani Shiv Nagar (U) BA011C 121.77 89.47 32.30 26.52 City BWN City BWN URBAN

BWN 17 132 Kv S/Stn Haluwas(Bhiwani) Patram Gate (U) BB141H 9.41 6.99 2.42 25.70 City BWN City BWN URBAN

BWN 18 132KV CH. DADRI -I M/G ROAD (U) BB122A 7.90 5.89 2.01 25.43 Dadri City Dadri URBAN

BWN 19 132 KV I/A BWN Panchayati Gate (U) BB103C 88.44 66.22 22.22 25.12 City BWN City BWN URBAN

BWN 20 33 KV S/STN. HUDA Pump H. Gujrani (U) BD221D 76.86 57.64 19.22 25.01 City BWN S/U-I URBAN

SRS 1 220 KV S/STN. RANIA Rania (MU) SA043A 159.61 100.45 59.17 37.07 S/U SRS Rania MIXED URBAN

SRS 2 220 KV S/STN. RANIA Gaushala (MU) SA041I 133.39 88.89 44.50 33.36 S/U SRS Rania MIXED URBAN

SRS 3 33 KV S/STN. Shergarh Mandi (U) SD401C 163.07 115.56 47.50 29.13 Dabwali Dabwali URBAN

SRS 4 33 KV S/STN. ELLENABAD RAILWAY ELLENABAD (U) SD091A 131.84 96.11 35.73 27.10 S/U SRS Ellenabad URBAN

SRS 5 33 KV S/STN. ELLENABAD By Pass (U) SD093D 32.23 23.98 8.25 25.58 S/U SRS Ellenabad URBAN

SRS 6 132 KV S/STN. DABWALI Mandi-III (U) SB051A 59.98 44.80 15.18 25.31 Dabwali Dabwali URBAN

JND 1 132 KV S/Stn. Uchana JTL (U) JB121D 181.34 62.71 118.63 65.42 Narwana Uchana URBAN

JND 2 132 KV S/Stn. Uchana Uchana (U) JB121E 158.25 56.56 101.69 64.26 Narwana Uchana URBAN

JND 3 132 KV Julana Julana-II (U) JB031B 23.24 9.79 13.45 57.89 Jind Julana URBAN

JND 4 132 KV S/Stn. (N) Narwana Uklana Road (MU) JB071B 132.35 57.54 74.82 56.53 Narwana City Narwana MIXED URBAN

JND 5 132 KV S/Stn. (N) Narwana Link (N) (U) JB071A 20.00 9.04 10.95 54.78 Narwana City Narwana URBAN

JND 6 132 KV Julana Julana (U) JB031A 194.16 92.88 101.28 52.16 Jind Julana URBAN

JND 7 132 KV S/Stn. (O) Narwana I.T.I. (U) JB081B 203.19 98.47 104.72 51.54 Narwana City Narwana URBAN

JND 8 132 KV S/Stn. (O) Narwana Model Town (U) JB083B 168.50 82.50 86.00 51.04 Narwana City Narwana URBAN

JND 9 132 KV S/Stn. (O) Narwana Link (O) (U) JB081C 109.62 53.95 55.68 50.79 Narwana City Narwana URBAN

JND 10 132 KV S/Stn. (O) Narwana City (U) JB081A 186.15 92.25 93.90 50.44 Narwana City Narwana URBAN

TOTAL OF 12 MONTHS

FEEDERWISE LOSSES OF 11 KV URBAN FEEDERS HAVING LOSSES MORE THAN 25% FY 2016-17N

AM

E

OF

CIR

CL

E

TO

TA

L

NO

. O

F

FE

ED

ER

S NAME OF FEEDING S/STN. NAME OF FEEDER FEEDER CODE

(FIGURES IN L.U.)

NAME OF OP

DIVISION

NAME OF OP SUB-

DIVISIONCATEGORY

UNIT


% LINE

LOSSES

TOTAL OF 12 MONTHS


AM

E

OF

CIR

CL

E

TO

TA

L

NO

. O

F

FE

ED

ER


(FIGURES IN L.U.)

NAME OF OP

DIVISION

NAME OF OP SUB-

DIVISIONCATEGORY

JND 11 132 KV S/Stn. Kheri taloda P.K. Mandi (U) JB141B 105.03 63.02 42.01 40.00 Safidon Pillukhera URBAN

JND 12 220 KV S/Stn. Safidon City -II (U) JA023B 160.28 103.19 57.09 35.62 Safidon City Safidon URBAN

JND 13 132 KV (O) Jind Empl. Colony (U) JB011I 62.39 41.71 20.68 33.15 Jind S/U No-2 URBAN

JND 14 132 KV (N) Jind Hansi Road (U) JB021K 153.05 103.01 50.04 32.70 Jind S/U No-2 URBAN

JND 15 132 KV (O) Jind Rohtak Road (U) JB011G 70.21 47.45 22.77 32.43 Jind S/U No-2 URBAN

JND 16 132 KV (N) Jind City -II (U) JB021J 225.65 154.94 70.70 31.33 Jind S/U No-2 URBAN

JND 17 33 KV S/S Safidon City -III (U) JD182F 147.78 103.92 43.86 29.68 Safidon City Safidon URBAN

JND 18 220 KV S/Stn. Safidon City -I (U) JA021B 171.57 122.26 49.31 28.74 Safidon City Safidon URBAN

JND 19 220 KV S/Stn. Safidon City -III (U) JA023E 12.74 9.16 3.58 28.10 Safidon City Safidon URBAN

JND 20 33 KV Pindara Court Road Jind (U) JD031B 19.90 14.53 5.37 26.98 Jind City Jind URBAN

JND 21 33 KV Pindara JIET (U) JD031K 35.73 26.15 9.58 26.82 Jind City Jind URBAN

JND 22 33 KV Pindara U/Estate (U) JD031G 176.96 130.05 46.91 26.51 Jind City Jind URBAN

JND 23 33 KV S/S Safidon Nagshetra (U) JD182G 23.28 17.11 6.17 26.49 Safidon City Safidon URBAN

JND 24 132 KV (N) Jind Link (U) JB021A 18.02 13.27 4.75 26.37 Jind S/U No-1 URBAN

JND 25 132 KV (O) Jind Link (U) JB011A 72.51 53.49 19.02 26.23 Jind S/U No-1 URBAN

FBD 1 66 KV NH-3 BADKHAL (U) FC071B 175.21 92.93 82.28 46.96 Old FBD No-IV URBAN

FBD 2 220 KV A-5 Sihi (U) FA022D 117.38 63.15 54.23 46.20 Ballabgarh Ind/Area URBAN

FBD 3 66 KV S/STN SECTOR-46 MEWLA M.PUR (U) FC061L 151.45 81.81 69.64 45.98 Old FBD No-IV URBAN

FBD 4 66 KV S/STN SECTOR-46 Ankhir (U) FC061J 166.06 90.33 75.73 45.60 Old FBD No-IV URBAN

FBD 5 220 KV PALI Naya Gaon (U) FA032D 123.33 75.56 47.76 38.73 Ballabgarh Pali URBAN

FBD 6 66 KV HYDERABAD N/HIGHWAY (U) FC151C 100.12 63.48 36.64 36.59 Ballabgarh S/U BLB URBAN

FBD 7 66 KV SECTOR-31 Mawai (U) Sec-31 FC123L 133.62 88.15 45.47 34.03 G.FBD Kheri Kalan URBAN

FBD 8 66 KV HYDERABAD Bansa Colony (U) FC153C 84.80 56.09 28.71 33.86 Ballabgarh S/U BLB URBAN

FBD 9 66 KV JHAR SETELY B/PETROLIUM (U) FC141C 102.14 67.71 34.44 33.71 Ballabgarh S/U BLB URBAN

FBD 10 66 KV JHAR SETELY SUNPAID (U) FC141O 88.44 59.56 28.87 32.65 Ballabgarh S/U BLB URBAN

FBD 11 66 KV ESCORTS SECTOR-15-B (U) FC051E 154.60 105.17 49.43 31.97 Old FBD East URBAN

FBD 12 66 KV A-4 Tigaon Road (U) FC111L 147.07 100.60 46.47 31.60 G.FBD Kheri Kalan URBAN

FBD 13 66 KV HYDERABADSAMAYPUR/RAJIV COLONY

(U)FC151F 85.17 59.24 25.93 30.44 Ballabgarh S/U BLB URBAN

FBD 14 220KV A3 PALLA Basantpur (U) FA013H 207.68 148.42 59.26 28.53 G.FBD Tilpat URBAN

FBD 15 220 KV PALI Nangla (U) FA032H 54.92 39.51 15.41 28.05 Ballabgarh Pali URBAN

FBD 16 66 KV A-4 INDIRA COMPLEX (U) FC111K 217.86 156.85 61.01 28.00 G.FBD Kheri Kalan URBAN

FBD 17 66 KV USA Anangpur (U) FC092D 236.70 172.25 64.45 27.23 Old FBD Mathura Road URBAN

FBD 18 220KV A3 PALLA KHERI KALAN (M/Road) (U) FA015J 126.69 92.28 34.41 27.16 G.FBD Tilpat URBAN

FBD 19 66 KV A-4 Padam Nagar (U) FC112F 193.98 142.02 51.96 26.79 G.FBD Kheri Kalan URBAN

FBD 20 220KV A3 PALLA PALLA (U) FA013G 221.95 162.86 59.09 26.62 G.FBD Tilpat URBAN

FBD 21 66 KV NH-3 Raja Chowk (U) FC072C 135.25 99.61 35.64 26.35 Old FBD No-IV URBAN

FBD 22 66 KV NH-3 S.G.M. C (U) FC071E 31.08 22.90 8.18 26.32 Old FBD No-IV URBAN

FBD 23 220KV A3 PALLA Surya Nagar (U) FA014K 100.96 74.50 26.46 26.21 G.FBD Tilpat URBAN

FBD 24 220 KV PALI Pali (U) FA032A 209.33 156.35 52.98 25.31 Ballabgarh Pali URBAN

FBD 25 66 KV NH-3 Gali No. 1 (U) FC071H 187.80 140.81 46.99 25.02 Old FBD No-IV URBAN

PWL 1 66KV Nagina City Nagina (U) PC152A 143.95 34.45 109.50 76.07 Nuh Nagina S/O URBAN

PWL 2 66KV Punhana City Punhana (U) PC161A 256.26 74.14 182.12 71.07 Nuh Punhana URBAN

PWL 3 33KV Pingwan Pingwan (U) PD051A 112.66 41.42 71.25 63.24 Nuh Nagina S/O URBAN

PWL 4 66KV Sohna City-III SOHNA (U) PC123H 143.56 52.99 90.57 63.09 Sohna Sohna URBAN

PWL 5 66KV Nuh City Nuh (U) PC141A 239.26 99.70 139.56 58.33 Nuh Nuh URBAN

PWL 6 66KV Sohna City-IV SOHNA (U) PC123J 139.60 62.62 76.97 55.14 Sohna Sohna URBAN

PWL 7 66KV Sohna City-I SOHNA (U) PC121D 119.11 57.76 61.35 51.51 Sohna Sohna URBAN

PWL 8 66 KV HATHIN Hathin (U) PC033A 144.48 74.17 70.31 48.66 Palwal Hathin URBAN

PWL 9 66KV Sohna City-II SOHNA (U) PC123A 134.96 70.97 63.99 47.41 Sohna Sohna URBAN

PWL 10 66 KV HODAL CITY-II HODAL (U) PC021B 96.56 57.48 39.09 40.48 Palwal Hodal URBAN

PWL 11 66 KV PALWAL CAMP (U) PC051K 119.88 71.36 48.52 40.47 Palwal City Pwl URBAN

PWL 12 66 KV HODAL CITY-III HODAL (U) PC021G 195.93 129.27 66.66 34.02 Palwal Hodal URBAN

PWL 13 66 KV PALWAL CITY-III PALWAL (U) PC051C 159.27 105.63 53.64 33.68 Palwal City Pwl URBAN

PWL 14 66 KV Huda Sec-2 City IV (U) PC171F 135.69 91.52 44.17 32.55 Palwal City Pwl URBAN

PWL 15 66 KV PALWAL Adarsh Colony (U) PC051F 181.87 123.25 58.62 32.23 Palwal City Pwl URBAN

PWL 16 66 KV Huda Sec-2 Minar gate (U) PC171C 112.02 76.08 35.95 32.09 Palwal City Pwl URBAN

PWL 17 66 KV Huda Sec-2 Kalyan Enclave (U) PC171B 109.60 75.38 34.22 31.22 Palwal City Pwl URBAN

PWL 18 66 KV PALWAL CITY-II PALWAL (U) PC051J 158.72 109.33 49.39 31.12 Palwal City Pwl URBAN

PWL 19 66 KV PALWAL I.T.I (U) PC051A 139.51 96.26 43.26 31.01 Palwal City Pwl URBAN

UNIT


% LINE

LOSSES

TOTAL OF 12 MONTHS


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(FIGURES IN L.U.)

NAME OF OP

DIVISION

NAME OF OP SUB-

DIVISIONCATEGORY

PWL 20 220 KV Megpur PALWAL HUDA SEC-2 (U) PA011F 152.07 104.98 47.09 30.97 Palwal City Pwl URBAN

PWL 21 66KV Nuh Civil Line Nuh (U) PC141G 16.97 11.90 5.06 29.84 Nuh Nuh URBAN

PWL 22 66 KV TAORU Taoru City -II (U) PC111C 179.12 126.21 52.90 29.54 Sohna Taoru Urban

PWL 23 66 KV Huda Sec-2 Huda-Sec-2 (U) PC171A 94.36 66.77 27.59 29.24 Palwal City Pwl URBAN

PWL 24 66 KV PALWAL Mohan Nagar (U) PC051B 176.66 126.47 50.19 28.41 Palwal S/U Pwl URBAN

PWL 25 66 KV PALWAL CITY-I PALWAL (U) PC051I 148.73 106.72 42.01 28.25 Palwal City Pwl URBAN

PWL 26 66 KV HODAL CITY-IV HODAL (Part-II) (U) PC021M 68.27 49.33 18.93 27.73 Palwal Hodal URBAN

PWL 27 66 KV TAORU TAORU CITY -I (U) PC112A 113.39 83.17 30.22 26.65 Sohna Taoru URBAN

PWL 28 33KV F.P.Zhirka CITY F/ZHIRKA (U) PD032A 185.94 138.17 47.76 25.69 Nuh F.Jhirka URBAN

GGN 1 220/66 KV S/STN Daultabad Daultabad (U) GA011A 106.30 66.45 39.85 37.49 City GGN New Palam Vihar URBAN

GGN 2 66KV S/STN SECTOR-2 Bajghera (MU) GC251I 156.57 99.68 56.89 36.34 City GGN New Palam Vihar MIX URBAN

GGN 3 66KV S/STN DLF(Q-Block) DLF Ph -III (U) GC052B 128.26 81.80 46.45 36.22 S/U GGN DLF URBAN

GGN 4 66 KV S/STN Sect-38 Wembley (U) GC231H 5.67 3.71 1.96 34.58 S/U GGN S/Road URBAN

GGN 5 220/66 KV S/STN Daultabad Dhanwapur Road (U) GA011B 155.16 103.37 51.79 33.38 City GGN New Palam Vihar URBAN

GGN 6 220/66 KV S/STN Daultabad Jahajgarh (U) GA013A 124.15 82.90 41.25 33.22 City GGN New Palam Vihar URBAN

GGN 7 66KV S/STN SECTOR-2 New Palam Vihar (U) (Sec-2) GC253J 157.42 107.81 49.61 31.51 City GGN New Palam Vihar URBAN

GGN 8 66KV S/STN SECTOR-2Dhanwapur Road/

Babaparkashspuri (U)GC251D 137.31 94.98 42.33 30.83 City GGN IDC URBAN

GGN 9 220/66 KV S/STN Daultabad Dhankot-II (U) GA013B 144.68 100.88 43.80 30.28 City GGN New Palam Vihar URBAN

GGN 10 220/66 KV S/STN Daultabad Rajindera Park (U) GA011D 170.47 119.29 51.19 30.03 City GGN New Palam Vihar URBAN

GGN 11 220/66 KV S/STN Daultabad Dharampur (U) GA013J 33.31 23.57 9.74 29.24 City GGN New Palam Vihar URBAN

GGN 12 66KV S/STN SECTOR-2 Sai Kunj (U) GC255A 50.09 35.65 14.44 28.83 City GGN New Palam Vihar URBAN

GGN 13 220/66 KV S/STN Daultabad Surat Nagar (U) GA011F 145.98 104.64 41.34 28.32 City GGN New Palam Vihar URBAN

GGN 14 220/66 KV S/STN Daultabad Vishnu Garden (U) GA013I 80.22 57.74 22.48 28.02 City GGN New Palam Vihar URBAN

GGN 15 220/66 KV S/STN Daultabad Sher Singh Vihar (U) GA013E 166.08 120.50 45.58 27.44 City GGN New Palam Vihar URBAN

NNL 1 132 kV S/Stn. Satnali Satnali (MU) NB041C 110.53 25.29 85.24 77.12 M/Garh S/U M/Garh MIXED URBAN

NNL 2 220 KV S/Stn. Narnaul Housing Board (MU) NA011B 68.70 28.75 39.95 58.15 Narnaul S/U Narnaul MIXED URBAN

NNL 3132 KV S/Stn.NANGAL

CHAUDHARYNANGAL CHAUDHARY (MU) NB023A 102.78 44.88 57.90 56.33 Narnaul N/Choudhary MIXED URBAN

NNL 4 132 KV S/Stn. Kanina City Kanina (MU) NB031A 166.80 92.24 74.56 44.70 M/Garh Kanina MIXED URBAN

NNL 5 33 KV S/Stn. Indl. Area NNL City-II (U) ND071H 119.13 72.45 46.68 39.18 Narnaul City Narnaul Urban

NNL 6 220 KV S/Stn. M/Garh CITY-II M/GARH (U) NA022E 141.14 88.65 52.50 37.19 M/Garh City M/Garh URBAN

NNL 7 132 KV S/Stn. Kanina City Kanina -II (MU) NB031L 41.19 27.35 13.84 33.59 M/Garh Kanina MIXED URBAN

NNL 8 33 KV S/Stn. Indl. Area NNL City-VIII (U) ND071K 29.02 19.38 9.64 33.23 Narnaul City Narnaul Urban

NNL 9 33 KV S/Stn. Indl. Area NNL City-VI (U) ND071F 119.47 80.67 38.81 32.48 Narnaul City Narnaul Urban

NNL 10 220 KV S/Stn. M/Garh CITY-I M/GARH (U) NA021A 179.86 133.96 45.90 25.52 M/Garh City M/Garh URBAN

RWR 1 66 KV S/Stn. Dharuhera Dharuhera (U) RC013A 193.18 117.30 75.88 39.28 Dharuhera Dharuhera URBAN

RWR 2 66 KV S/Stn. Dharuhera Complex (U) RC012C 151.42 102.91 48.50 32.03 Dharuhera Dharuhera URBAN

RWR 3 33 KV S/Stn. Model Town Daliyawas (MU) RD012C 72.76 49.61 23.15 31.82 Rewari S/U Rewari MIXED URBAN

RWR 4 132 KV S/Stn. Bawal Bawal (U) RB041A 164.29 113.46 50.83 30.94 Dharuhera Bawal URBAN

RWR 5 220 KV S/Stn. Rewari B. B. Ashram (MU) RA0126A 188.50 132.81 55.68 29.54 Rewari S/U Rewari MIXED URBAN

RWR 6 33 KV S/Stn. Sec.10 Rewari Vijay Nagar (U) RD071A 57.34 42.90 14.45 25.19 Rewari S/U Rewari URBAN

UNIT


% LINE

LOSSES

HSR 1 33 KV BUDANA BUDANA DS HD651C 110.41 6.62 103.79 94.01 HANSI NARNAUND RDS

HSR 2 132 KV NARNAUND. UGALAN DS HB073D 101.01 10.54 90.48 89.57 HANSI NARNAUND RDS

HSR 3 33 KV BITHMARA CHITAIN DS HD691E 31.20 3.29 27.91 89.46 TOHANA UKLANA RDS

HSR 4 132 KV UKLANA DAULATPUR DS HB131I 137.50 14.98 122.52 89.10 TOHANA UKLANA RDS

HSR 5 33 KV SULCHANI SULCHANI DS HD601A 43.35 5.11 38.24 88.20 HANSI NARNAUND RDS

HSR 6 33 KV BARWALA DHAD DS HD042E 114.36 13.83 100.53 87.91 HISAR-II BARWALA RDS

HSR 7 33 KV BARWALA CHHAN DS HD042F 81.52 9.99 71.52 87.74 HISAR-II BARWALA RDS

HSR 8 33 KV BASS UGALAN DS HD061G 48.95 6.00 42.95 87.74 HANSI MUNDHAL RDS

HSR 9 33 KV MIRCHPUR MIRCHPUR DS HD671A 63.89 8.09 55.80 87.33 HANSI NARNAUND RDS

HSR 10 33 KV BITHMARA BITHMARA DS HD691A 119.98 15.30 104.68 87.25 TOHANA UKLANA RDS

HSR 11 33 KV BASS BADCHAPER DS HD061F 81.00 10.95 70.05 86.48 HANSI MUNDHAL RDS

HSR 12 33 KV UMRA SULTANPUR DS HD561E 53.07 7.26 45.81 86.32 HANSI UMRA RDS

HSR 13 33 KV MUNDHAL MADANHERI DS HD403B 77.07 10.75 66.32 86.06 HANSI MUNDHAL RDS

HSR 14 33KV SISAI PALI DS HD141A 49.12 7.01 42.11 85.73 HANSI SISAI RDS

HSR 15 132 KV NARNAUND. MIRCHPUR DS HB071C 84.54 12.17 72.37 85.60 HANSI NARNAUND RDS

HSR 16 33 KV BASS BASS DS HD061A 115.89 16.77 99.12 85.53 HANSI MUNDHAL RDS

HSR 17 33KV SISAI GAGAN KHERI DS HD141E 87.76 12.71 75.05 85.52 HANSI SISAI RDS

HSR 18 33 KV CHAMAR KHERA KHAIRY DS HD 211E 60.28 8.95 51.33 85.16 TOHANA UKLANA RDS

HSR 19 33 KV BARSI ALAKHPURA DS HD711C 42.43 6.30 36.13 85.16 HANSI S/U HANSI RDS

HSR 20 33 KV BHATLA KHARKARI DS HD372D 74.24 11.11 63.13 85.04 HISAR-II BARWALA RDS

HSR 21 132 KV UKLANA LITANI DS HB131A 74.99 11.28 63.71 84.96 TOHANA UKLANA RDS

HSR 22 33 KV KOTH KOTH KALAN DS HD121E 123.64 18.63 105.01 84.93 HANSI NARNAUND RDS

HSR 23 33 KV BARWALA KUMBHA DS HD042A 79.66 13.61 66.05 82.92 HISAR-II BARWALA U/RDS

HSR 24 33 KV UMRA HAZAMPUR DS HD561F 107.54 19.29 88.26 82.07 HANSI UMRA RDS

HSR 25 33 KV THURANA BHATOL DS HD621B 69.57 12.54 57.03 81.98 HANSI NARNAUND RDS

HSR 26 33 KV THURANA PETWAR DS HD621F 78.00 14.13 63.86 81.88 HANSI NARNAUND RDS

HSR 27 33 KV THURANA THURANA DS HD621A 46.45 8.43 38.02 81.86 HANSI NARNAUND RDS

HSR 28 33 KV BASS BADALA DS HD061E 34.17 6.23 27.94 81.76 HANSI MUNDHAL RDS-J

HSR 29 33 KV MASUDPUR MASUDPUR DS HD631A 44.03 8.22 35.81 81.34 HANSI S/U HANSI RDS-J

HSR 30 33 KV LEHRIAN SINTHLA DS HD542B 27.50 5.18 22.32 81.16 TOHANA BHUNA RDS

HSR 31 33 KV MIRCHPUR MILKPUR DS HD671C 28.04 5.37 22.66 80.84 HANSI NARNAUND RDS-J

HSR 32 33 KV UMRA UMRA DS HD561A 69.93 13.43 56.50 80.80 HANSI UMRA RDS-J

HSR 33 33 KV KOTH KAPRO DS HD121B 87.52 16.90 70.61 80.69 HANSI NARNAUND RDS

HSR 34 33 KV BHATLA DHARAMPURA DS HD371B 37.22 7.25 29.97 80.52 HANSI S/U HANSI RDS

HSR 35 33 KV MUNDHAL SORKHI DS HD401B 66.46 13.47 52.99 79.73 HANSI MUNDHAL RDS

HSR 36 33 KV BHATLA LALPURA DS HD371D 101.50 20.61 80.89 79.69 HANSI S/U HANSI RDS

HSR 37 33 KV PIRTHLA PARTA DS HD521B 71.09 14.59 56.50 79.48 TOHANA S/U TOHANA RDS

HSR 38 33 KV MAJRA MAJRA DS HD611A 33.80 7.06 26.74 79.12 HANSI NARNAUND RDS-J

HSR 39 33 KV SOTTAR BHATTU BHATTU DS HD791A 3.55 0.75 2.80 78.84 FATEHABAD S/U FATEHABAD RDS

HSR 40 33 KV CHAMAR KHERA CHAMAR KHERA DS HD 211A 73.59 15.70 57.89 78.66 TOHANA UKLANA RDS

HSR 41 33 KV UMRA BHAGANA DS HD561G 74.31 16.29 58.02 78.08 HANSI UMRA RDS-J

HSR 42 33 KV MUNDHAL KUNGAR DS HD401A 51.02 11.29 39.73 77.87 HANSI MUNDHAL RDS-J

HSR 43 33 KV MANGALI DHAMANA DS HD331E 102.47 22.89 79.57 77.66 HISAR-II SATROD RDS

HSR 44 33 KV MUNDHAL MUNDHAL DS HD401C 102.31 22.90 79.41 77.62 HANSI MUNDHAL RDS

HSR 45 33 KV MASUDPUR DATA DS HD631G 63.12 14.21 48.92 77.49 HANSI S/U HANSI RDS

HSR 46 33 KV NANGLA NANGLA DS HD701B 54.74 12.34 42.40 77.45 TOHANA CITY TOHANA RDS-J

HSR 47 33 KV CHANDER KHURD BHODIAKHERA DS HD681G 8.66 1.98 6.68 77.14 TOHANA S/U TOHANA RDS

HSR 48 33 KV JAMALPUR JAMALPUR DS HD221D 84.55 19.39 65.16 77.07 TOHANA S/U TOHANA RDS-J

HSR 49 33 KV THURANA KUMBA DS HD621C 35.56 8.20 27.36 76.94 HANSI NARNAUND RDS-J

HSR 50 33 KV BHATLA SINDHAR DS HD372B 33.94 7.87 26.07 76.82 HANSI S/U HANSI RDS

HSR 51 33 KV BARSI MEHNDA DS HD711E 65.81 15.31 50.50 76.73 HANSI S/U HANSI RDS

HSR 52 33 KV BHUNA BALANWALI DS HD261D 94.52 22.30 72.22 76.40 TOHANA BHUNA RDS

HSR 53 33 KV MASUDPUR SINGHWA DS HD631C 56.16 13.26 42.90 76.39 HANSI S/U HANSI RDS

HSR 54 33 KV BARSI MILKPUR-1 DS HD711B 68.67 16.23 52.45 76.37 HANSI S/U HANSI RDS

HSR 55 33 KV RAINWALI UDEYPUR DS HD512H 53.98 13.12 40.86 75.70 TOHANA S/U TOHANA RDS

HSR 56 33 KV SARSOD BARKI KHERI DS HD052C 66.56 16.34 50.23 75.46 HISAR-II BARWALA RDS

HSR 57 33 KV BHATLA MAJOD DS HD371A 14.47 3.56 10.91 75.39 HANSI S/U HANSI RDS

HSR 58 33KV SISAI SISAI DS HD141D 86.65 21.51 65.13 75.17 HANSI SISAI RDS

HSR 59 33 KV RAINWALI CHILEWAL DS HD511E 16.10 4.11 12.00 74.50 TOHANA S/U TOHANA RDS

HSR 60 33 KV CHANDER KHURD CHANDER DS HD681B 87.55 22.42 65.13 74.39 TOHANA S/U TOHANA RDS

HSR 61 33 KV SHARWA DUBETHA DS HD231B 60.93 15.78 45.15 74.10 HISAR-II SATROD RDS

TOTAL OF 12 MONTHS

FEEDERWISE LOSSES OF 11 KV RDS FEEDERS HAVING LOSSES MORE THAN 50% IN FY 2016-17N

AM

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(FIGURES IN L.U.)

NAME OF OP

DIVISION

NAME OF OP SUB-

DIVISIONCATEGORY

UNIT


% LINE

LOSSES

TOTAL OF 12 MONTHS


AM

E

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CIR

CL

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TO

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NO

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F

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(FIGURES IN L.U.)

NAME OF OP

DIVISION

NAME OF OP SUB-

DIVISIONCATEGORY

HSR 62 33 KV NADHORI GHOTRU DS HD581G 11.13 2.96 8.18 73.45 TOHANA BHUNA RDS

HSR 63 33 KV MAJRA MOTH DS HD611C 102.25 27.18 75.07 73.42 HANSI NARNAUND RDS-J

HSR 64 33 KV BARSI BARSI DS HD711A 44.59 11.95 32.64 73.21 HANSI S/U HANSI RDS

HSR 65 132 KV UKLANA SAHU DS HB131G 122.01 32.94 89.07 73.00 TOHANA UKLANA RDS

HSR 66 132 KV UKLANA GAJUWALA DS HB131B 51.99 14.05 37.94 72.98 TOHANA UKLANA RDS-J

HSR 67 33 KV MUNDHAL KHARKRA DS HD402C 35.78 9.81 25.96 72.57 HANSI MUNDHAL RDS

HSR 68 33 KV NEHLA GORKHPUR DS HD282E 76.61 21.12 55.49 72.43 TOHANA BHUNA RDS

HSR 69 132 KV KHEDAR DHANI GARAN DS HB191B 141.58 39.17 102.41 72.33 HISAR-II BARWALA RDS-J

HSR 70 33 KV BEHBALPUR HANSPUR DS HD411F 52.44 14.78 37.66 71.82 FATEHABAD S/U FATEHABAD RDS

HSR 71 33 KV RAINWALI LALUWAL DS HD512E 19.43 5.49 13.94 71.75 TOHANA S/U TOHANA RDS

HSR 72 33 KV ARYA NAGAR DHIRANWAS DS HD311G 51.78 15.35 36.43 70.36 HISAR-II BALSAMAND RDS

HSR 73 33 KV MANGALI HARIKOT DS HD331F 25.73 8.00 17.74 68.93 HISAR-II SATROD RDS

HSR 74 33 KV GORAKHPUR GORAKHPUR DS HD751B 25.85 8.06 17.79 68.80 TOHANA BHUNA RDS

HSR 75 33 KV BHIWANI ROHILA KHARIA DS HD361H 52.98 16.55 36.43 68.77 HISAR-II BALSAMAND RDS

HSR 76 132 KV DHARSHUL MANGHERA DS HB121N 74.40 23.27 51.13 68.72 TOHANA S/U TOHANA RDS

HSR 77 33 KV AYALKI BAROTA DS HD482E 24.94 7.83 17.11 68.61 FATEHABAD S/U RATIA RDS

HSR 78 33 KV NANGTHLA SHAMSUKH DS HD091B 6.16 1.96 4.19 68.11 HISAR-II AGROHA RDS

HSR 79 33 KV Burak BALSAMAND DS HD591D 79.54 25.40 54.14 68.07 HISAR-II BALSAMAND RDS

HSR 80 33 KV BARWALA PANIHARI DS HD041D 129.41 41.46 87.95 67.96 HISAR-II BARWALA RDS

HSR 81 33 KV AGROHA KIRMARA DS HD342A 82.06 26.76 55.30 67.39 HISAR-II AGROHA RDS-J

HSR 82 132 KV BARWALA GAIBIPUR DS HB021C 127.73 41.84 85.89 67.24 HISAR-II BARWALA RDS-J

HSR 83 33 KV BHUNA DHANI GOPAL DS HD262E 22.58 7.49 15.09 66.84 TOHANA BHUNA RDS

HSR 84 33 KV SHARWA PAYAL DS HD232B 49.73 16.59 33.14 66.65 HISAR-II SATROD RDS

HSR 85 33 KV Burak BURAK DS HD591B 16.50 5.54 10.96 66.42 HISAR-II BALSAMAND RDS-J

HSR 86 33 KV HAROLI J.P ADDA DS HD492F 59.10 19.87 39.23 66.38 FATEHABAD S/U RATIA RDS-J

HSR 87 220 KV INDUSTRIAL AREA MIRZAPUR DS HA011H 84.47 28.77 55.70 65.95 HISAR-II SATROD RDS

HSR 88 33 KV NANGTHLA DURJANPUR DS HD092A 62.35 21.30 41.05 65.84 HISAR-II AGROHA RDS

HSR 89 33 KV BEHBALPUR MUSEALI DS HD412D 25.63 8.86 16.77 65.44 FATEHABAD S/U FATEHABAD RDS

HSR 90 33 KV KARANDI ROOPANWALI DS HD551D 54.18 18.90 35.28 65.12 TOHANA S/U TOHANA RDS

HSR 91 132 KV HANSI T-1A-1B MILAKPUR DS HB061J 20.79 7.30 13.49 64.90 HANSI S/U HANSI RDS

HSR 92 33 KV LEHRIAN REHAN KHERI DS HD542D 10.79 3.82 6.97 64.60 TOHANA BHUNA RDS

HSR 93 33 KV BARWALA ROAD HANSI SAINIPURA DS HD391D 74.49 26.39 48.10 64.57 HANSI S/U HANSI RDS-J

HSR 94 132 KV TELIWARA TELIWARA DS HB141I 55.29 19.79 35.50 64.21 FATEHABAD CITY RATIA RDS

HSR 95 33 KV GULARWALA AKANWALI DS HD241H 38.00 13.76 24.24 63.78 TOHANA S/U TOHANA RDS-J

HSR 96 33 KV LEHRIAN LEHRIAN DS HD541B 19.72 7.18 12.54 63.61 TOHANA BHUNA RDS

HSR 97 220 KV INDUSTRIAL AREA NEW TIBBA LINE DS HA011E 98.06 35.83 62.23 63.46 HISAR-II SATROD RDS-J

HSR 98 33 KV BHIWANI ROHILA KIRTAN DS HD361D 57.81 21.17 36.64 63.38 HISAR-II BALSAMAND RDS

HSR 99 33 KV SARSOD SARSOD DS HD052H 20.36 7.46 12.90 63.35 HISAR-II BARWALA RDS-J

HSR 100 33 KV BUDANA RAKHI DS HD651D 71.31 26.48 44.82 62.86 HANSI NARNAUND RDS

HSR 101 132 KV HANSI T-1C KHERI DAULATPUR DS HB063H 53.20 19.84 33.36 62.70 HANSI S/U HANSI RDS

HSR 102 33 KV NEHLA SIWANI DS HD282A 90.49 33.91 56.58 62.52 TOHANA BHUNA RDS

HSR 103 33 KV DHABI KALAN JANDWALA DS HD271C 49.13 18.62 30.51 62.10 FATEHABAD BHATTU RDS

HSR 104 33 KV MODA KHERA MODA KHERA DS HD101G 23.82 9.05 14.76 61.99 HISAR-II ADAMPUR RDS

HSR 105 33 KV BHUTHAN PANDRI DS HD112G 32.57 12.40 20.17 61.92 TOHANA BHUNA RDS

HSR 106 33 KV BODIWALI BODIWALI DS HD641A 20.69 8.05 12.64 61.08 FATEHABAD S/U FATEHABAD RDS

HSR 107 33 KV BHUNA BHATTU DS HD262F 25.87 10.16 15.71 60.71 TOHANA BHUNA RDS

HSR 108 132 KV BHATTU THUIYAN DS HB151I 76.02 29.89 46.13 60.68 FATEHABAD BHATTU RDS

HSR 109 33KV KAMANA KAMANA DS HD131F 28.09 11.11 16.98 60.45 FATEHABAD CITY RATIA RDS

HSR 110 33 KV BADOPAL KAJAL-HERI DS HD442C 136.59 54.27 82.32 60.27 FATEHABAD BADOPAL RDS-J

HSR 111 132 KV ARYA NAGAR BHERIYA DS HB181A 24.09 9.82 14.27 59.25 HISAR-II SATROD RDS-J

HSR 112 132 KV HANSI T-1C PREM NAGAR DS HB063G 50.86 20.96 29.90 58.78 HANSI S/U HANSI RDS-J

HSR 113 132 KV ADAMPUR KHARAMPUR DS HB051L 35.78 14.76 21.02 58.75 HISAR-II ADAMPUR RDS

HSR 114 33 KV BADOPAL BHODA DS HD441A 69.21 28.56 40.65 58.73 FATEHABAD BADOPAL RDS

HSR 115 33 KV SECTOR-13 MIRKAN DS HD322F 51.26 21.21 30.05 58.62 HISAR-II SATROD RDS

HSR 116 33 KV SHARWA SHARWA DS HD231F 28.85 12.23 16.62 57.62 HISAR-II SATROD U/RDS-J

HSR 117 33 KV AYALKI KHUMBAR DS HD489A 53.46 22.84 30.63 57.28 FATEHABAD S/U RATIA RDS

HSR 118 33 KV NANHERI NANHERI DS HD 201A 22.57 9.77 12.80 56.71 FATEHABAD CITY RATIA RDS-J

HSR 119 33 KV GANDHA/AJIT NAGAR AJIT NAGAR DS HD292B 55.73 24.16 31.57 56.65 FATEHABAD S/U RATIA RDS

HSR 120 33 KV DHABI KALAN DHABI KALAN DS HD271A 16.75 7.27 9.48 56.60 FATEHABAD BHATTU RDS

HSR 121 33 KV BADOPAL DHARNIA DS HD442G 45.67 20.06 25.61 56.08 FATEHABAD BADOPAL RDS

HSR 122 33 KV S/S DARIYAPUR DARIYAPUR VILLAGE DS HD151C 69.20 30.97 38.22 55.24 FATEHABAD S/U FATEHABAD RDS

UNIT


% LINE

LOSSES

TOTAL OF 12 MONTHS


AM

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CIR

CL

E

TO

TA

L

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(FIGURES IN L.U.)

NAME OF OP

DIVISION

NAME OF OP SUB-

DIVISIONCATEGORY

HSR 123 33 KV S/S DARIYAPUR KUKRANWALI DS HD152C 33.95 15.24 18.71 55.11 FATEHABAD S/U FATEHABAD RDS

HSR 124 33 KV ARYA NAGAR LUDAS -II DS HD311F 86.76 39.25 47.52 54.77 HISAR-II ADAMPUR RDS

HSR 125 33 KV HAZRAWAN KALAN DHANI GURNAM DS HD071E 55.68 25.19 30.50 54.77 FATEHABAD S/U FATEHABAD RDS

HSR 126 132 KV ADAMPUR CHIKANWAS DS HB051K 51.21 23.21 28.00 54.68 HISAR-II AGROHA RDS

HSR 127 33 KV NADHORI NADHORI DS HD581B 21.51 10.02 11.49 53.40 TOHANA BHUNA RDS

HSR 128 33 KV DHANI BABANPUR DHANI BABANPUR DS HD771F 5.87 2.76 3.10 52.93 FATEHABAD CITY RATIA RDS

HSR 129 132 KV AHERWAN BEHAL BHUMIA-II DS HB101K 10.81 5.12 5.70 52.70 FATEHABAD S/U RATIA RDS-J

HSR 130 33 KV GULARWALA LEKHUWAL DHANI DS HD241D 39.07 18.75 20.33 52.02 TOHANA S/U TOHANA RDS-J

HSR 131 33 KV SISWAL BAGLA DS HD352D 56.57 27.31 29.27 51.73 HISAR-II ADAMPUR RDS

HSR 132 33 KV AGROHA KALIRAWAN DS HD341B 134.33 65.04 69.28 51.58 HISAR-II AGROHA RDS

HSR 133 33 KV HAROLI HAROLI DS HD492D 30.80 15.19 15.61 50.69 FATEHABAD S/U RATIA RDS-J

HSR 134 33 KV RATIA BHARPUR DS HD722C 17.22 8.52 8.70 50.51 FATEHABAD CITY RATIA RDS-J

HSR 135 33 KV DEGOH DEGOH DS HD252D 28.19 13.96 14.23 50.48 TOHANA BHUNA RDS-J

HSR 136 33 KV SADHANWASCHANDPURA + MUNDLIAN

DSHD532E 30.60 15.16 15.44 50.46 TOHANA JAKHAL RDS

HSR 137 132 KV BHUTHAN KALAN DHANI MAJRA DS HB171A 43.01 21.45 21.56 50.14 FATEHABAD S/U FATEHABAD RDS-J

BWN 1 132KV CH. DADRI II. Charkhi U DS BB131H 79.25 10.25 69.00 87.07 Dadri City Dadri U/RDS

BWN 2 132KV CH. DADRI II. Fathegarh DS BB131J 107.54 14.62 92.92 86.40 Dadri City Dadri RDS

BWN 3 33 KV RD-0 Rawaldhi DS BD131B 19.69 3.44 16.25 82.52 Dadri City Dadri RDS

BWN 4 33 KV MORWALA Morwala DS BD151F 128.57 23.21 105.36 81.95 Dadri S/U Dadri RDS

BWN 5 33KV MAKRANA Datoli Ds BD141G 4.14 0.77 3.37 81.38 Dadri S/U Dadri RDS

BWN 6 33 KV MORWALA Bhagwi DS BD151E 110.67 21.09 89.58 80.94 Dadri S/U Dadri RDS

BWN 7 132KV CH. DADRI II. KITLANA DS BB131B 118.30 22.85 95.45 80.69 Dadri City Dadri RDS

BWN 8 33 KV SANJARWAS Achina DS BD123C 94.36 18.85 75.51 80.02 Dadri Sanjarwas RDS

BWN 9 33 KV SANJARWAS Bass DS BD122E 66.54 13.36 53.18 79.92 Dadri Sanjarwas RDS

BWN 10 33 KV Kakroli Sardara Kakroli Hati DS BD331B 64.41 13.50 50.91 79.04 Dadri Badhra RDS

BWN 11 33 KV SANJARWAS Manheru/SANWAR DS BD123E 53.48 11.76 41.72 78.01 Dadri Sanjarwas RDS

BWN 12 33 KV RD-0 Ghikara DS BD132D 17.63 3.90 13.73 77.86 Dadri City Dadri RDS-J

BWN 13 33 KV Dheraru Manheru DS BD521E 89.42 20.65 68.77 76.91 Dadri Sanjarwas RDS

BWN 14 33 KV SANJARWAS Bound kalan DS BD123D 111.38 26.39 85.00 76.31 Dadri Sanjarwas RDS

BWN 15 33KV Nandha Nandha-II DS BD312B 39.46 9.36 30.10 76.29 Dadri Badhra RDS

BWN 16 132 KV ATELA KALAN Doka Hariya DS BB072H 50.88 12.19 38.69 76.04 Dadri Atela Kalan RDS

BWN 17 33 KV SANJARWAS Malkosh DS BD123F 38.51 9.23 29.28 76.03 Dadri Sanjarwas RDS

BWN 18 33KV MAKRANA Patuwas DS BD141H 53.46 12.85 40.61 75.97 Dadri S/U Dadri RDS

BWN 19 33 KV Dheraru Dhareru DS BD521A 39.89 9.89 30.00 75.21 Dadri Sanjarwas RDS

BWN 20 33 KV Ghasola Ghasola U DS BD491A 31.92 7.91 24.00 75.20 Dadri S/U Dadri U/RDS-J

BWN 21 33 KV Dheraru Badala DS BD521D 77.01 19.55 57.46 74.61 Dadri Sanjarwas RDS

BWN 22 33 KV S/Stn Mandhana Dhanana DS BD561A 94.65 24.06 70.59 74.58 City BWN B/Khera RDS

BWN 23 132 KV S/Stn. JUI Khairpura DS BB032I 38.75 10.25 28.50 73.54 S/U BWN Jui RDS

BWN 24 33 Kv S/Stn Leghan(B) Jitwan Bas DS BD471A 12.29 3.26 9.03 73.46 S/U BWN Jui RDS

BWN 25 33 KV S/Stn. Bawani Khera Pur DS BD022B 72.64 19.32 53.33 73.41 City BWN B/Khera RDS

BWN 26 33 KV CHHAPPAR Pandwan DS BD321E 55.35 14.97 40.38 72.95 Dadri Atela Kalan RDS

BWN 27 33 KV S/STN. CHANG Badeshra DS BD232E 58.39 15.81 42.58 72.93 City BWN B/Khera RDS

BWN 28 33 KV S/Stn. Bawani Khera Talu DS BD022E 62.35 16.89 45.45 72.90 City BWN B/Khera RDS

BWN 29 33KV MAKRANA Makrani-II DS BD141F 57.08 15.73 41.35 72.44 Dadri S/U Dadri RDS

BWN 30 33 KV MANDHI Dalawas DS BD202C 65.20 18.39 46.81 71.80 Dadri Badhra RDS

BWN 31 132 KV BADHRA Nimar Badesra U DS BB082E 92.41 27.33 65.08 70.43 Dadri Badhra U/RDS-J

BWN 32 33 KV S/S Lohani Ashalwas DS BD062C 64.53 19.11 45.41 70.38 S/U BWN Jui RDS

BWN 33 33 KV MANDOLA Chillar DS BD411D 50.90 15.16 35.75 70.22 Dadri Jhojhu Kalan RDS

BWN 34 33 KV CHHAPPAR Chappar DS BD321A 36.94 11.02 25.92 70.16 Dadri Atela Kalan RDS-J

BWN 35 33 KV S/S Lohani Leghan DS BD061D 40.26 12.09 28.17 69.97 S/U BWN Jui RDS

BWN 36 33 KV S/Stn. Nakipur Nakipur DS BD053D 30.40 9.21 21.19 69.70 S/U BWN D/Jattan RDS

BWN 37 33 KV LAD LAD-II DS BD211D 31.14 9.51 21.63 69.47 Dadri Badhra RDS

BWN 38 33 KV SANJARWAS PHOGAT DS BD123A 93.66 28.70 64.96 69.35 Dadri Sanjarwas RDS

BWN 39 132KV S/STN Kairu Kairu DS BB151A 56.98 17.71 39.27 68.91 S/U BWN Jui RDS

BWN 40 132KV JHOJHU KALAN Badhwana DS BB093E 35.21 11.15 24.06 68.34 Dadri Jhojhu Kalan RDS

BWN 41 33 KV RUDROL Mai Khurd DS BD171E 52.33 16.69 35.64 68.10 Dadri Jhojhu Kalan RDS

BWN 42 33 KV S/S Lohani Chain Pura DS BD062F 52.05 16.69 35.35 67.93 S/U BWN Jui RDS

BWN 43 132 KV ATELA KALAN BINDRABAN DS BB072G 52.46 17.00 35.46 67.60 Dadri Atela Kalan RDS

BWN 44 33 KV S/Stn. Devrala Ladiawali DS BD091H 67.12 21.82 45.30 67.49 S/U BWN Jui RDS

BWN 45 33 KV RUDROL Bijna DS BD171F 44.48 14.58 29.90 67.22 Dadri Jhojhu Kalan RDS

UNIT


% LINE

LOSSES

TOTAL OF 12 MONTHS


AM

E

OF

CIR

CL

E

TO

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L

NO

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F

FE

ED

ER


(FIGURES IN L.U.)

NAME OF OP

DIVISION

NAME OF OP SUB-

DIVISIONCATEGORY

BWN 46 33 KV S/Stn. Kari Dharni Kari Dharni DS BD281B 37.84 12.41 25.43 67.21 S/U BWN D/Jattan RDS

BWN 47 33 KV S/Stn. Dawarka Bhopali DS BD082D 45.47 14.95 30.53 67.13 S/U BWN D/Jattan RDS

BWN 48 33KV S/STN Nangla Nangla DS BD391A 20.42 6.84 13.58 66.51 S/U BWN Jui RDS

BWN 49 33 KV PICHOPA Kubja Nagar-II DS BD451D 44.83 15.04 29.79 66.44 Dadri Jhojhu Kalan RDS

BWN 50 33 KV CHHAPPAR Narshinghawas DS BD321D 34.82 11.69 23.14 66.44 Dadri Atela Kalan RDS

BWN 51 33KV BERLA Berla DS BD181E 82.64 27.84 54.80 66.31 Dadri Badhra RDS

BWN 52 33 KV S/Stn Chandwas Chandwas DS BD481E 19.96 6.77 13.19 66.10 Dadri Badhra RDS

BWN 53 33 KV S/Stn. Bawani Khera Jatu lohari DS BD021A 41.20 14.02 27.18 65.97 City BWN B/Khera RDS

BWN 54 132KV JHOJHU KALAN Kaliyana DS BB093F 67.21 23.07 44.13 65.67 Dadri Jhojhu Kalan RDS

BWN 55 33 KV KADMA KADMA-II DS BD192B 76.01 26.10 49.91 65.66 Dadri Jhojhu Kalan RDS

BWN 56 33 KV SISHWALA Tiwala DS BD301D 31.78 11.03 20.74 65.28 Dadri Atela Kalan RDS

BWN 57 33 KV MANDOLA Mandola DS BD411E 23.92 8.32 15.60 65.23 Dadri Jhojhu Kalan RDS

BWN 58 33 KV Ghasola Mouri DS BD491D 44.07 15.35 28.72 65.17 Dadri S/U Dadri RDS

BWN 59 33kv S/STN Pohkarwas Pohkarwas DS BD401C 65.07 22.78 42.29 64.99 S/U BWN Jui RDS

BWN 60 33 KV S/Stn. chahar kalan Ch. Khurd DS BD261D 31.59 11.28 20.31 64.30 S/U BWN D/Jattan RDS

BWN 61 33 KV S/Stn. Devrala Siharpur DS BD091G 19.90 7.11 12.79 64.26 S/U BWN Jui RDS

BWN 62 132 KV S/Stn. JUI Dhani Jattan DS BB032J 16.19 5.82 10.37 64.03 S/U BWN Jui RDS

BWN 63 33 KV S/Stn. Budheda Manfera DS BD271B 31.54 11.43 20.11 63.76 S/U BWN D/Jattan RDS

BWN 64 132 KV I/A BWN Bamla DS BB101F 147.76 53.97 93.78 63.47 City BWN S/U-II RDS

BWN 65 33 KV S/Stn. Budheda Bhungla DS BD271A 24.44 8.94 15.50 63.42 S/U BWN D/Jattan RDS

BWN 66 33 KV S/Stn Mandhana Tigrana DS BD561C 85.76 31.75 54.01 62.98 City BWN B/Khera RDS

BWN 67 33KV S/Stn Singhani Gobindpura DS BD161E 60.56 22.83 37.73 62.30 S/U BWN D/Jattan RDS

BWN 68 33 KV Dohka Deena Dohka Deena DS BD461C 75.07 28.39 46.68 62.18 Dadri Atela Kalan RDS

BWN 69 33 KV S/Stn Mandhana Mandhana DS BD561B 35.57 13.48 22.09 62.10 City BWN B/Khera RDS-J

BWN 70 33 KV Kakroli Sardara Umarwas DS BD331E 26.00 9.96 16.04 61.69 S/U BWN Jui RDS

BWN 71 33 KV S/STN. CHANGCHANG New DS(33 KV

CHANG)BD232A 76.00 29.30 46.70 61.45 City BWN S/U-II RDS-J

BWN 72 33 KV S/Stn. Nakipur Bhaghasara DS BD053E 17.83 6.88 10.95 61.42 S/U BWN D/Jattan RDS

BWN 73 132 Kv S/Stn Haluwas(Bhiwani) Uttam Nagar DS BB141D 47.80 18.74 29.06 60.80 City BWN S/U-II RDS-J

BWN 74 132 KV S/Stn. D./Jattan D/Mandi U DS BB022G 66.69 26.19 40.50 60.73 S/U BWN D/Jattan U/RDS

BWN 75 132 Kv S/Stn Haluwas(Bhiwani) Nimriwali DS BB141B 84.15 33.18 50.97 60.57 City BWN S/U-II RDS

BWN 76 33 KV S/STN. CHANG Mitathal DS BD232D 93.59 37.11 56.48 60.35 City BWN S/U-II RDS

BWN 77 132KV JHOJHU KALAN JHOJHU DS BB093C 181.94 73.60 108.34 59.54 Dadri Jhojhu Kalan RDS

BWN 78 132KV JHOJHU KALAN Gokal DS BB093G 51.73 20.96 30.77 59.47 Dadri Jhojhu Kalan RDS

BWN 79 33 KV S/STN. CHANG SAI DS BD232B 73.45 30.05 43.39 59.08 City BWN S/U-II RDS

BWN 80 33 KV SANJARWAS Sanjarwas DS BD121C 38.43 15.76 22.68 59.00 Dadri Sanjarwas RDS-J

BWN 81 132 KV 6.3 MVA Old BWN Prem Nagar DS BB011E 37.22 15.56 21.67 58.21 City BWN S/U-II RDS

BWN 82 33 KV Changroad Badhwana DS BD551C 70.20 29.38 40.81 58.14 Dadri Jhojhu Kalan RDS

BWN 83 33 KV S/S Lohani DEVSAR DS(33 KV LOHANI) BD062B 69.57 29.51 40.06 57.58 City BWN S/U-II RDS

BWN 84 132 Kv S/Stn Haluwas(Bhiwani) Pehlad Garh DS BB141E 63.64 27.54 36.10 56.72 City BWN S/U-II RDS

BWN 85 132 Kv S/Stn Haluwas(Bhiwani) Dhana Ladanpur DS BB141C 37.33 16.66 20.67 55.38 City BWN S/U-II RDS

BWN 86 33 KV S/Stn. SIWANI Khera DS BD101E 72.14 33.39 38.75 53.71 S/U BWN Siwani RDS

BWN 87 132 KV S/Stn. JUI Jui City DS BB032G 52.51 24.90 27.61 52.58 S/U BWN Jui RDS-J

BWN 88 132KV S/Stn LOHARU Barwas DS BB061O 60.04 29.66 30.38 50.60 S/U BWN Loharu RDS

SRS 1 132 KV S/STN. ASSA KHERA Bharu Khera DS SB041G 4.10 0.70 3.40 83.03 Dabwali Chautala RDS

SRS 2 132 KV S/STN. JIWAN NAGAR Santawali DS SB033N 19.76 5.04 14.72 74.49 S/U SRS Rania RDS

SRS 3 33 KV S/STN. KASUMBI Tazia -II DS SD211G 32.70 9.36 23.34 71.37 S/U SRS Nathusari RDS

SRS 4 33 KV S/STN. NATHUSARI Kairanwali DS SD082D 59.99 21.25 38.74 64.58 S/U SRS Nathusari RDS

SRS 5 132 KV S/STN. KARIWALA Mandi Kariwala U DS SB061P 44.25 15.85 28.40 64.18 S/U SRS J. Nagar U/RDS

SRS 6 33 KV S/STN. NATHUSARI Rupana DS SD082C 54.86 19.76 35.10 63.98 S/U SRS Nathusari RDS

SRS 7 33 KV S/STN. Haripura Haripura U DS SD371A 20.91 7.80 13.11 62.70 S/U SRS J. Nagar U/RDS

SRS 8 33 KV S/STN. Chautala Chautala U DS SD491A 65.30 25.49 39.81 60.97 Dabwali Chautala U/RDS

SRS 9 33 KV S/STN. NATHUSARI Jamal DS SD081E 143.51 56.47 87.03 60.65 S/U SRS Nathusari RDS

SRS 10 33 KV S/STN. Kagdana Jogiwala DS SD301D 42.46 17.08 25.39 59.78 S/U SRS Nathusari RDS

SRS 11 33 KV S/STN. Mohmadpuria Balasar DS SD261E 70.06 31.94 38.13 54.42 S/U SRS Rania RDS

SRS 12 33 KV S/STN. Dadu Dadu U DS SD451A 21.20 9.73 11.46 54.07 Dabwali Kalanwali U/RDS

SRS 13 33 KV S/STN. Mastangarh Mastangarh DS SD361A 27.52 12.82 14.71 53.43 S/U SRS J. Nagar RDS

SRS 14 132 KV S/STN. ASSA KHERA Farm House U DS SB041C 7.28 3.48 3.80 52.26 Dabwali Chautala U/RDS

SRS 15 33 KV S/STN. Chautala Bharu Khera DS SD491B 16.22 7.97 8.24 50.84 Dabwali Chautala RDS

SRS 16 33 KV S/STN. Kagdana Gusaiyana DS SD301E 45.79 22.62 23.17 50.60 S/U SRS Nathusari RDS

UNIT


% LINE

LOSSES

TOTAL OF 12 MONTHS


AM

E

OF

CIR

CL

E

TO

TA

L

NO

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F

FE

ED

ER


(FIGURES IN L.U.)

NAME OF OP

DIVISION

NAME OF OP SUB-

DIVISIONCATEGORY

JND 1 132 KV S/Stn. Dhanouri Dhanouri DS JB111F 147.26 13.94 133.32 90.53 Narwana Garhi RDS

JND 233 KV S/Stn. Sanghan (Under

Kaithal Circle)Sinand DS JKD031D 40.83 4.33 36.50 89.39 Narwana Garhi RDS

JND 3 33 KV Shri Rag Khera Dalamwala DS JD021I 72.08 7.68 64.41 89.35 Jind Naguran RDS

JND 433 KV S/Stn. Sanghan (Under

Kaithal Circle)Barta DS JKD031A 39.87 4.38 35.49 89.01 Narwana Garhi RDS

JND 5 33 KV S/Stn. Kharal Kharal (Hamirgarh) DS JD101C 100.51 11.44 89.06 88.61 Narwana Garhi RDS

JND 6 132 KV S/Stn. (N) Narwana Dumarkha DS JB071E 175.59 20.44 155.15 88.36 Narwana City Narwana RDS

JND 7 33 KV Alewa Bhigana DS JD071B 68.73 8.24 60.49 88.01 Jind Naguran RDS

JND 8 132 KV S/Stn. Garhi Ujhana DS JB101G 102.00 14.56 87.44 85.73 Narwana Garhi RDS

JND 9 132 KV Naguran Mandi DS JB042A 66.59 9.72 56.86 85.40 Jind Naguran RDS

JND 10 33 KV S/Stn. Pipaltha Pipaltha DS JD151C 44.13 6.66 37.47 84.90 Narwana Garhi RDS-J

JND 11 33 KV S/Stn. Pipaltha Padarth khera DS JD152A 73.41 11.58 61.84 84.23 Narwana Garhi RDS

JND 12 33 KV Shamdo Shamdo DS JD061C 113.09 17.92 95.17 84.15 Jind Naguran RDS-J

JND 13 33 KV S/Stn. Rasidan Rasidan DS JD111A 37.80 6.05 31.75 84.00 Narwana Garhi RDS-J

JND 14 33 KV Alewa Alewa DS JD073B 136.41 21.91 114.51 83.94 Jind Naguran RDS

JND 15 33 KV S/S Gangoli Bhirtana DS JD241B 61.43 10.01 51.42 83.70 Safidon Pillukhera RDS

JND 16 33 KV S/S Kheri taloda Assan DS JD223B 106.12 17.63 88.49 83.39 Safidon Pillukhera RDS

JND 17 33 KV S/Stn. Chatter Chattar DS JD161A 112.64 19.03 93.61 83.11 Narwana Uchana RDS

JND 18 33 KV Naguran Shahpur DS JD011D 60.99 10.32 50.67 83.08 Jind Naguran RDS

JND 19 33 KV Pindara Sindhvi Khera DS JD031D 85.45 14.51 70.94 83.02 Jind S/U No-2 RDS

JND 20 33 KV Badhana Dehola DS JD081B 102.48 17.48 85.00 82.95 Jind Naguran RDS

JND 21 132 KV Julana Lajwana DS JB031C 129.60 22.12 107.48 82.93 Jind Julana RDS

JND 22 33 KV Pindara Ludana DS JD031F 86.72 14.82 71.90 82.91 Jind S/U No-2 RDS-J

JND 23 33 KV S/Stn. Kakrod Kakrod DS JD171A 98.12 16.85 81.26 82.82 Narwana Uchana RDS

JND 24 33 KV S/S Kheri Bullan Bullan DS JD301A 0.91 0.16 0.76 82.78 Jind Naguran RDS

JND 25 33 KV S/Stn. Chatter Karsindhu DS JD161D 121.61 21.04 100.56 82.70 Narwana Uchana RDS

JND 26 132 KV S/Stn. Ghogrian Roj Khera DS JB131A 130.13 22.70 107.42 82.55 Narwana Uchana RDS

JND 27 33 KV Desh Khera Desh Khera DS JD281E 3.86 0.67 3.18 82.50 Jind Julana RDS

JND 2833 KV S/Stn. Kheri Sher Khan

(Under Kaithal Circle)Sinsar-I DS JKD021F 119.29 20.91 98.38 82.47 Narwana S/U Narwana RDS

JND 29 132 KV Julana Nand Garh DS JB031G 87.58 15.46 72.12 82.35 Jind Julana RDS

JND 30 132 KV S/Stn. Uchana Durjanpur DS JB121B 103.21 18.32 84.88 82.25 Narwana Uchana RDS

JND 31 132 KV S/Stn. Uchana Kharak Bura DS JB121C 90.19 16.07 74.12 82.19 Narwana Uchana RDS

JND 32 132 KV S/Stn. Ghogrian Kasoon DS JB131B 61.76 11.07 50.69 82.08 Narwana Uchana RDS

JND 33 33 KV Kinana Brar Khera DS JD051A 64.34 11.58 52.76 82.01 Jind S/U No-2 RDS

JND 34 33 KV S/Stn. Kakrod Makhand DS JD171C 62.38 11.33 51.05 81.84 Narwana Uchana RDS

JND 35 132 KV Bibipur Ramgarh DS JB061F 67.94 12.46 55.48 81.67 Jind S/U No-2 RDS-J

JND 36 132 KV Bibipur Bibipur DS JB061D 105.57 19.47 86.10 81.56 Jind S/U No-2 RDS

JND 37 33 KV S/S Gangoli Gangoli U DS JD241A 52.12 9.65 42.47 81.48 Safidon Pillukhera U/RDS-J

JND 38 33 KV Pindara Pindara DS JD031E 149.09 27.65 121.45 81.46 Jind S/U No-2 RDS

JND 3933 KV S/Stn. Kheri Sher Khan

(Under Kaithal Circle)Kamalpur DS JKD021E 28.48 5.36 23.12 81.18 Narwana Uchana RDS-J

JND 40 132 KV S/Stn. Garhi Garhi DS JB101A 67.42 12.97 54.45 80.77 Narwana Garhi RDS

JND 41 33 KV S/Stn. Mangalpur Mangalpur DS JD261B 41.79 8.15 33.64 80.50 Narwana S/U Narwana RDS

JND 42 33 KV S/S Manoharpur. Khunga DS JD233B 47.37 9.29 38.08 80.39 Safidon Pillukhera RDS

JND 43 33 KV S/S Kheri taloda Lohchab DS JD221B 119.57 24.36 95.21 79.63 Safidon Pillukhera RDS

JND 44 33 KV Kinana Kinana DS JD051E 80.77 16.76 64.00 79.25 Jind Julana RDS

JND 45 33 KV S/S Sindvi Khera Dhigana DS JD291D 10.15 2.13 8.02 79.02 Jind S/U No-2 RDS

JND 46 33 KV S/Stn. Belarkha Belarkha DS JD091D 76.28 16.05 60.23 78.96 Narwana S/U Narwana RDS

JND 47 33 KV S/S Sindvi Khera Bhero Khera DS JD291B 5.89 1.24 4.65 78.91 Jind S/U No-2 RDS

JND 48 132 KV S/Stn. Kheri taloda Bhurain DS JB141I 97.48 20.63 76.86 78.84 Safidon Pillukhera RDS-J

JND 49 33 KV S/Stn. Guruser Bhana DS JD141E 65.57 13.97 51.60 78.70 Narwana S/U Narwana RDS

JND 50 33 KV S/S Gangoli Morkhi DS JD242B 114.19 24.44 89.75 78.60 Safidon Pillukhera RDS

JND 51 132 KV Julana Hathwala DS JB031F 105.48 22.62 82.86 78.55 Jind Julana RDS

JND 52 132 KV S/Stn. Kheri taloda Beri Khera DS JB141G 84.06 18.06 66.00 78.52 Safidon Pillukhera RDS

JND 53 33 KV Shri Rag Khera Kandela DS JD021C 57.84 12.71 45.13 78.02 Jind Naguran RDS

JND 54 33 KV S/S Sindvi Khera Sindvi Khera DS JD291C 8.58 1.94 6.64 77.44 Jind S/U No-2 RDS

JND 55 33 KV S/S Sindvi Khera Nidani DS JD291E 7.13 1.63 5.50 77.16 Jind S/U No-2 RDS

JND 56 33 KV S/S Manoharpur. Habatpur DS JD232A 96.73 22.12 74.62 77.14 Jind S/U No-1 RDS-J

JND 57 33 KV S/Stn. Mangalpur Dohana Khera DS JD261C 13.38 3.08 10.30 77.00 Narwana S/U Narwana RDS

UNIT


% LINE

LOSSES

TOTAL OF 12 MONTHS


AM

E

OF

CIR

CL

E

TO

TA

L

NO

. O

F

FE

ED

ER


(FIGURES IN L.U.)

NAME OF OP

DIVISION

NAME OF OP SUB-

DIVISIONCATEGORY

JND 58 33 KV Ramrai Ponkeri Kheri DS JD041J 53.30 12.29 41.02 76.95 Jind S/U No-1 RDS

JND 59 33 KV S/Stn. Danoda Saccha khera DS JD132A 112.33 26.42 85.91 76.48 Narwana S/U Narwana RDS

JND 60 33 KV Badhana Badhana DS JD081A 35.86 8.47 27.38 76.37 Jind Naguran RDS-J

JND 61 33 KV S/Stn. Lochab Phullian DS JD121D 63.57 15.07 48.50 76.29 Narwana S/U Narwana RDS

JND 62 33 KV S/Stn. Lochab Kaloda DS JD121A 69.80 16.60 53.20 76.22 Narwana S/U Narwana RDS

JND 63 33 Kv S/Stn. Gatauli Karela DS JD251A 112.39 26.82 85.57 76.14 Jind Julana RDS

JND 64 132 KV S/Stn. Dhamtan Sulehra DS JB093D 87.08 20.99 66.10 75.90 Narwana S/U Narwana RDS

JND 65 132 KV Naguran Naguran DS JB041A 102.60 24.90 77.70 75.73 Jind Naguran RDS

JND 66 132 KV S/Stn. Dhamtan Loan DS JB091C 53.50 13.02 40.47 75.66 Narwana S/U Narwana RDS

JND 67 132 KV S/Stn. Dhamtan Kalwan DS JB091G 90.36 22.08 68.27 75.56 Narwana S/U Narwana RDS

JND 68 132 KV (N) Jind Sangatpura DS JB021H 119.06 29.53 89.52 75.19 Jind S/U No-1 RDS

JND 69 132 KV Julana Malvi DS JB031D 101.90 25.74 76.15 74.74 Jind Julana RDS

JND 70 33 KV Ramrai Ram Rai DS JD041D 99.60 25.18 74.42 74.72 Jind S/U No-1 RDS

JND 71 33 KV Kinana Ram Kali DS JD051F 100.68 25.67 75.01 74.50 Jind Julana RDS

JND 72 132 KV (N) Jind Barsola DS JB021G 121.63 31.38 90.25 74.20 Jind S/U No-1 RDS

JND 73 33 KV S/S Singhana Muwana DS JD192D 134.88 35.03 99.85 74.03 Safidon City Safidon RDS

JND 74 33 KV S/S Singhana Bhadurgarh DS JD191C 74.88 19.53 55.35 73.91 Safidon City Safidon RDS

JND 75 33 KV S/S Singhana Aftabgarh DS JD191B 103.68 27.13 76.55 73.83 Safidon City Safidon RDS

JND 76 132 KV S/Stn. (O) Narwana Badanpur DS JB083A 103.45 27.35 76.10 73.56 Narwana S/U Narwana RDS

JND 77 220 KV S/Stn. Jhanjh Khatkar DS JA011A 102.64 27.46 75.18 73.24 Jind S/U No-1 RDS

JND 78 220 KV S/Stn. Jhanjh Roopgarh DS JA011F 56.03 15.12 40.91 73.02 Jind S/U No-1 RDS

JND 79 33 KV S/Stn. Danoda Danoda DS JD131C 114.16 31.00 83.16 72.84 Narwana S/U Narwana RDS-J

JND 80 33 KV S/S Didwara Nimnabad DS JD212C 93.26 25.97 67.29 72.15 Safidon S/U Safidon RDS-J

JND 81 33 KV S/Stn. Danoda Jajanwala DS JD131A 57.92 16.37 41.54 71.73 Narwana S/U Narwana RDS

JND 8233 KV S/Stn. Koth (Under Hansi

Division)Khaper DS JHD011A 42.66 12.07 30.59 71.70 Narwana Uchana RDS-J

JND 83 33 KV S/S Singhana Singhana DS JD192C 53.35 15.15 38.20 71.61 Safidon City Safidon RDS-J

JND 84 33 KV S/Stn. Belarkha Mohal Khera DS JD091B 2.69 0.77 1.92 71.47 Narwana S/U Narwana RDS

JND 85 33 KV S/Stn. Guruser Gurusar DS JD141E 15.28 4.41 10.87 71.15 Narwana S/U Narwana RDS-J

JND 86 132 KV S/Stn. Kheri taloda Jamni DS JB141F 68.96 19.94 49.02 71.08 Safidon Pillukhera RDS-J

JND 87 33 KV Alewa Alewa Anaj Mandi DS JD071F 0.88 0.26 0.62 70.97 Jind Naguran RDS

JND 88 33 KV Desh Khera Malvi DS JD281D 17.33 5.21 12.12 69.91 Jind Julana RDS-J

JND 89 33 Kv S/Stn. Gatauli Karsola DS JD251E 45.64 13.76 31.88 69.85 Jind Julana RDS

JND 90 33 KV S/S Hatt Bhadurpur DS JD202A 92.90 28.41 64.49 69.41 Safidon S/U Safidon RDS

JND 91 33 KV S/S Hatt Harigarh DS JD202D 105.54 32.74 72.80 68.97 Safidon S/U Safidon RDS-J

JND 92 132 KV S/Stn. Dhamtan Dhamtan DS JB091B 90.62 28.66 61.96 68.38 Narwana S/U Narwana RDS

JND 93 33 KV S/S Hatt Anchra Kalan DS JD201E 83.44 26.69 56.75 68.02 Safidon S/U Safidon RDS

JND 94 33 KV S/Stn. Dhamtan Dhamtan DS JD271A 42.73 13.87 28.85 67.53 Narwana S/U Narwana RDS-J

JND 95 220 KV S/Stn. Jhanjh Amarheri DS JA011G 86.37 28.63 57.74 66.85 Jind S/U No-1 RDS-J

JND 96 33 KV S/S Hatt Mallar DS JD201B 72.05 24.97 47.08 65.34 Safidon S/U Safidon RDS

JND 97 220 KV S/Stn. Safidon Karsindhu DS JA021A 81.15 28.35 52.80 65.06 Safidon S/U Safidon RDS

JND 98 132 KV S/Stn. (O) Narwana Tohana Road DS JB083D 108.59 39.56 69.03 63.57 Narwana S/U Narwana RDS

JND 99 33 Kv S/Stn. Gatauli Gatauli DS JD251B 56.71 21.01 35.70 62.95 Jind Julana RDS-J

JND 100 132 KV S/Stn. (N) Narwana Dhakal DS JB071H 78.46 32.84 45.61 58.14 Narwana S/U Narwana RDS

JND 101 220 KV S/Stn. Safidon Malikpur DS JA023H 33.60 14.10 19.50 58.04 Safidon S/U Safidon RDS-J

JND 102 132 KV S/Stn. Dablain Dablain DS JB151A 49.46 20.79 28.68 57.98 Narwana S/U Narwana RDS-J

JND 103 33 KV S/S Didwara Didwara DS JD212E 13.51 6.44 7.06 52.30 Safidon S/U Safidon RDS

FBD 1 66 KV FATEHPUR BILOCH Behbalpur DS FC241B 57.87 12.92 44.96 77.68 G.FBD Chhainsa RDS

FBD 2 66 KV Sector-64 Chandawali DS FC211I 209.35 47.60 161.75 77.26 G.FBD Badrola U/RDS-J

FBD 3 33 KV S/Stn. Gharora Gharora DS FD031A 77.92 19.03 58.89 75.58 G.FBD Badrola RDS

FBD 4 220 KV A-5 N.T.P.C. DS FA021K 230.23 56.49 173.74 75.46 G.FBD Badrola U/RDS-J

FBD 5 66 KV CHHAINSA Walipur DS FC251E 78.72 19.97 58.75 74.63 G.FBD Chhainsa RDS-J

FBD 6 66 KV CHHAINSA HEERAPUR DS FC252D 52.16 13.45 38.71 74.21 G.FBD Chhainsa RDS-J

FBD 7 66 KV S/STN BADROLA CHANDPUR DS FC231H 59.34 15.32 44.02 74.18 G.FBD Badrola RDS

FBD 8 66 KV S/STN BADROLA NEEMKA DS FC231F 73.13 20.12 53.02 72.49 G.FBD Badrola RDS

FBD 9 66 KV S/STN BADROLA Kaurali DS FC233D 57.82 16.48 41.34 71.49 G.FBD Badrola RDS

FBD 10 66 KV S/STN BADROLA MANJHAWALI DS FC233F 35.00 10.10 24.90 71.14 G.FBD Badrola RDS

FBD 11 66 KV S/STN BADROLA DAYALPUR DS FC231G 90.71 26.68 64.03 70.59 G.FBD Badrola RDS

FBD 12 33 KV S/Stn. Atali Atali DS FD021B 72.61 23.41 49.20 67.76 G.FBD Chhainsa RDS-J

FBD 13 66 KV CHHAINSA DULEHPUR DS FC252E 60.67 19.84 40.83 67.29 G.FBD Chhainsa RDS

FBD 14 66 KV Sector-64 Sotai DS FC212G 28.71 10.47 18.24 63.54 G.FBD Badrola RDS-J

UNIT


% LINE

LOSSES

TOTAL OF 12 MONTHS


AM

E

OF

CIR

CL

E

TO

TA

L

NO

. O

F

FE

ED

ER


(FIGURES IN L.U.)

NAME OF OP

DIVISION

NAME OF OP SUB-

DIVISIONCATEGORY

FBD 15 66 KV S/STN BADROLA TIGAON DS FC233E 201.86 85.20 116.66 57.79 G.FBD Badrola RDS-J

FBD 16 66 KV A-4 KHERI KALAN DS FC111J 131.18 60.35 70.83 54.00 G.FBD Kheri Kalan RDS-J

FBD 17 66 KV BHOPANI Badarpur Sad DS FC133E 64.45 29.87 34.58 53.66 G.FBD Kheri Kalan RDS

FBD 18 66 KV FORD Badoli Ford DS FC083E 131.32 62.80 68.52 52.18 G.FBD Kheri Kalan RDS-J

FBD 19 66 KV DHOUJ Manger DS FC221C 90.59 43.56 47.03 51.91 Ballabgarh Pali RDS-J

FBD 20 66 KV DHOUJ Kot DS FC221D 115.02 55.85 59.17 51.45 Ballabgarh Pali RDS

PWL 1 33KV Agon Nangal DS PD091E 0.29 0.02 0.27 92.02 Nuh F.Jhirka RDS

PWL 2 66KV Nuh Meoli -II DS PC141I 96.71 9.97 86.74 89.69 Nuh Nuh RDS

PWL 3 33KV Rojka Meo Khori Basai DS PD022H 81.89 11.29 70.60 86.21 Sohna Sohna RDS-J

PWL 4 33KV Rojka Meo Hirmathla DS PD022G 89.11 13.32 75.78 85.05 Sohna Sohna RDS

PWL 5 33KV Bhadas Jalalpur DS PD041B 97.01 15.51 81.49 84.01 Nuh Nagina S/O RDS

PWL 6 33KV Bhadas GHAGAS-II DS PD041C 61.60 10.04 51.56 83.70 Nuh Nagina S/O RDS

PWL 7 66KV Nagina Shekpur DS PC151E 62.45 11.13 51.31 82.17 Nuh Nagina S/O RDS

PWL 8 66KV Nuh Alduka DS PC141O 78.81 14.20 64.61 81.98 Nuh Nuh RDS-J

PWL 9 66KV Punhana Naheda DS PC161E 89.82 16.67 73.15 81.44 Nuh Punhana RDS-J

PWL 10 66KV Nuh Ujjina DS PC141C 127.78 24.77 103.00 80.61 Nuh Nuh RDS

PWL 11 33KV Dondal Luhinga DS PD061D 86.32 17.22 69.10 80.05 Nuh Punhana RDS

PWL 12 33KV Pingwan Lahabass DS PD051C 70.05 14.46 55.59 79.36 Nuh Nagina S/O RDS-J

PWL 13 66KV Nagina Nawli DS PC151C 60.14 12.63 47.51 79.00 Nuh Nagina S/O RDS

PWL 14 33KV Sakras Sakras DS PD071A 90.26 19.15 71.11 78.78 Nuh Nagina S/O RDS

PWL 15 33KV Pingwan Tigaon DS PD051F 71.42 15.38 56.04 78.46 Nuh Nagina S/O RDS

PWL 16 220 KV Megpur PALWAL ALLIKA DS PA011K 102.37 22.10 80.27 78.41 Palwal S/U Pwl RDS-J

PWL 17 66 KV CHANDHUT Rahimpur DS PC041K 100.00 22.15 77.85 77.85 Palwal S/U Pwl RDS

PWL 18 66 KV CHANDHUT GURWARI DS PC041H 104.34 23.19 81.15 77.78 Palwal S/U Pwl RDS

PWL 19 33KV Dondal Malhaka DS PD061E 46.99 10.48 36.51 77.71 Nuh Punhana RDS-J

PWL 20 220 KV Megpur PALWAL Ghugera DS PA011L 109.70 24.83 84.87 77.36 Palwal S/U Pwl RDS-J

PWL 21 66KV Nuh Ghasera DS PC141B 111.38 25.35 86.03 77.24 Nuh Nuh RDS-J

PWL 22 66KV Sohna Berka DS PC121I 130.73 30.46 100.27 76.70 Sohna Sohna RDS

PWL 23 66KV Punhana Singar DS PC161C 100.98 23.55 77.43 76.68 Nuh Punhana RDS

PWL 24 33KV Pingwan SHIKRAWAN DS PD051E 101.29 23.81 77.48 76.49 Nuh Nagina S/O RDS-J

PWL 25 66KV Punhana Jamalgarh-I DS PC161L 33.18 7.92 25.26 76.12 Nuh Punhana RDS-J

PWL 26 66 KV CHHAINSA NANGLIA DS PC061C 70.57 16.86 53.71 76.11 Palwal S/U Pwl RDS

PWL 27 66KV Punhana Bichore DS PC161N 59.46 14.27 45.19 76.01 Nuh Punhana RDS

PWL 28 66KV Punhana Shah Chokha DS PC161J 75.71 18.17 57.54 76.00 Nuh Punhana RDS

PWL 29 66 KV Allawalpur Chirwari DS PC071K 108.02 26.04 81.98 75.89 Palwal S/U Pwl RDS

PWL 30 33KV Dondal Dondal DS PD061C 24.60 6.15 18.45 75.00 Nuh Punhana RDS-J

PWL 31 66 KV Allawalpur Dadota DS PC071J 63.55 16.06 47.49 74.73 Palwal S/U Pwl RDS

PWL 32 66 KV Allawalpur Ghagot DS PC071I 62.56 16.50 46.06 73.63 Palwal S/U Pwl RDS-J

PWL 33 66 KV Allawalpur Gannika DS PC071H 120.96 32.82 88.14 72.87 Palwal S/U Pwl RDS

PWL 34 66KV Nagina Badarpur DS PC152B 97.19 27.13 70.06 72.09 Nuh Nagina S/O RDS

PWL 35 66KV Nuh Adbar DS PC141K 111.92 31.51 80.40 71.84 Nuh Nuh RDS-J

PWL 36 33KV Dondal Jamalgarh-II DS PD061A 43.58 12.28 31.30 71.81 Nuh Punhana RDS

PWL 37 33KV Agon Rawli DS PD091A 16.23 4.62 11.62 71.56 Nuh F.Jhirka RDS

PWL 38 33KV F.P.Zhirka Bhond DS PD032E 67.34 19.51 47.83 71.02 Nuh F.Jhirka RDS-J

PWL 39 220 KV Megpur PALWAL Kalwaka DS PA011M 99.84 30.61 69.23 69.34 Palwal S/U Pwl RDS

PWL 40 66 KV Mandkola Mandnaka DS PC101F 98.21 30.62 67.59 68.83 Palwal Mandkola S/O RDS

PWL 41 66 KV Mandkola Lalwa DS PC101G 76.93 25.22 51.71 67.22 Palwal Mandkola S/O RDS

PWL 42 66 KV Mandkola Dungerpur DS PC101H 90.83 29.80 61.03 67.19 Palwal Mandkola S/O RDS

PWL 43 66 KV HATHIN Khandawali DS PC033B 111.43 36.69 74.74 67.07 Palwal Hathin RDS

PWL 44 66 KV HATHIN Maluka DS PC031L 61.92 20.49 41.43 66.91 Palwal Hathin RDS

PWL 45 66KV Nuh Mallab DS PC141D 114.63 38.46 76.16 66.45 Nuh Nuh RDS

PWL 46 66KV Punhana Bisru DS PC161D 92.98 31.22 61.75 66.42 Nuh Punhana RDS

PWL 47 33KV Agon Maholi DS PD091B 16.03 5.39 10.64 66.37 Nuh F.Jhirka RDS

PWL 48 66KV Sohna Indri DS PC123C 178.38 60.96 117.42 65.83 Sohna Sohna RDS

PWL 49 66 KV HATHIN Chhainsa DS PC031H 46.48 15.94 30.54 65.70 Palwal Hathin RDS

PWL 50 66 KV HATHIN Jodhpur DS PC031I 91.67 31.67 60.01 65.46 Palwal Hathin RDS

PWL 51 66 KV HATHIN Kalinger DS PC031C 67.90 23.46 44.44 65.44 Palwal Hathin RDS

PWL 52 66 KV Baghola Gadpuri DS PC091J 149.18 51.84 97.34 65.25 Palwal S/U Pwl RDS

PWL 53 33KV F.P.Zhirka Bhond -II DS PD032J 2.08 0.73 1.35 64.78 Nuh F.Jhirka RDS

PWL 54 66 KV HATHIN Uttawar DS PC031E 64.22 22.88 41.34 64.38 Palwal Hathin RDS

PWL 55 66 KV Nimoth Chamanpura DS PC131A 98.54 35.72 62.82 63.75 Sohna Sohna RDS-J

UNIT


% LINE

LOSSES

TOTAL OF 12 MONTHS


AM

E

OF

CIR

CL

E

TO

TA

L

NO

. O

F

FE

ED

ER


(FIGURES IN L.U.)

NAME OF OP

DIVISION

NAME OF OP SUB-

DIVISIONCATEGORY

PWL 56 33KV F.P.Zhirka Biwan -II DS PD031A 79.06 28.89 50.16 63.45 Nuh F.Jhirka RDS

PWL 57 66 KV HODAL SEVLI DS PC021C 133.03 48.73 84.30 63.37 Palwal Hodal RDS

PWL 58 33 KV Bahin Powser DS PD011C 96.45 35.60 60.85 63.09 Palwal Hathin RDS

PWL 59 66KV Punhana Gulalta DS PC161M 40.50 15.10 25.40 62.71 Nuh Punhana RDS

PWL 60 33KV F.P.Zhirka Rawa DS PD032D 47.25 18.03 29.21 61.83 Nuh F.Jhirka RDS-J

PWL 61 33 KV Bahin Manpur DS PD011A 95.23 38.36 56.87 59.72 Palwal Hathin RDS-J

PWL 62 66 KV HATHIN Gehlab U DS PC033D 65.35 26.64 38.71 59.24 Palwal Hathin U/RDS-J

PWL 63 66 KV HATHIN Kondal U DS PC031K 106.44 43.53 62.91 59.11 Palwal Hathin U/RDS-J

PWL 64 33 KV Bahin BAHIN DS PD011B 63.61 26.03 37.57 59.07 Palwal Hathin RDS-J

PWL 65 66 KV HASSANPUR Gulawad DS PC012C 97.01 42.60 54.42 56.09 Palwal Hassanpur RDS-J

PWL 66 66 KV Nimoth Nimoth DS PC131D 57.18 25.15 32.03 56.02 Sohna Sohna RDS-J

PWL 67 66 KV HASSANPUR Achheja DS PC011K 85.82 37.78 48.04 55.97 Palwal Hassanpur RDS

PWL 68 66 KV HODAL Bahin DS PC021L 117.25 55.47 61.78 52.69 Palwal Hodal RDS-J

PWL 69 66 KV HATHIN Jainpur DS PC033C 68.88 32.83 36.05 52.33 Palwal Hathin RDS-J

PWL 70 66 KV CHANDHUT Kithwari DS PC041J 87.57 42.34 45.24 51.66 Palwal S/U Pwl RDS-J

PWL 71 66 KV Huda Sec-2 Firojpur DS PC171G 40.45 19.62 20.84 51.51 Palwal S/U Pwl RDS-J

NNL 1 33 KV S/Stn. Kheri Gahra DS ND371I 35.64 2.69 32.95 92.45 M/Garh Kanina RDS

NNL 233 KV PUMP HOUSE MC-III (CKT-I

M/GARH)Karira DS ND143A 50.27 6.05 44.21 87.96 M/Garh Kanina RDS

NNL 3 33 KV S/Stn. Shyampura Shyampura DS ND401A 2.72 0.36 2.36 86.91 M/Garh S/U M/Garh RDS

NNL 4 33 KV S/Stn. Pathera Buchawas DS ND341A 52.49 6.92 45.57 86.81 M/Garh Kanina RDS-J

NNL 5 132 kV S/Stn. Satnali Sohri DS NB041I 84.27 14.52 69.76 82.77 M/Garh S/U M/Garh RDS

NNL 633 KV PUMP HOUSE MC-V (CKT-I

M/GARH)Jhagroli DS ND163B 28.35 5.36 22.99 81.10 M/Garh Kanina RDS

NNL 7 33 KV S/Stn. Nangal Serohi Nangal-Sirohi DS ND081F 40.31 7.98 32.33 80.21 M/Garh S/U M/Garh RDS

NNL 8 33 KV S/Stn. Nangal Serohi Nihalawas DS ND082B 100.92 19.98 80.94 80.20 M/Garh S/U M/Garh RDS

NNL 9 33 KV S/Stn. Jant Khudana DS ND111E 83.94 17.26 66.68 79.44 M/Garh City M/Garh RDS

NNL 10 33 KV S/Stn. Sehlang Sehlang DS ND231F 55.26 11.41 43.85 79.35 M/Garh City M/Garh RDS-J

NNL 11 33 KV S/Stn. Barda Barda DS ND102C 63.04 13.38 49.66 78.78 M/Garh S/U M/Garh RDS

NNL 12 33 KV S/Stn. Bawania Meghanwas DS ND222D 96.04 20.46 75.58 78.70 M/Garh City M/Garh RDS

NNL 13 33 KV S/Stn. Budeen Balaicha DS ND271E 64.56 13.85 50.71 78.55 M/Garh S/U M/Garh RDS

NNL 14 33 KV S/Stn. Khatoti God DS ND012E 121.60 26.16 95.44 78.48 Narnaul S/U Narnaul RDS

NNL 15 132 KV S/Stn. Mundia-Khera Mudian DS NB051I 77.81 16.93 60.88 78.24 M/Garh S/U M/Garh RDS

NNL 16 33 KV S/Stn. Rambass Bharaf DS ND361F 35.05 7.67 27.38 78.13 M/Garh Kanina RDS

NNL 17 33 KV S/Stn. Majra Bhagdana DS ND251F 74.96 16.50 58.46 77.98 M/Garh City M/Garh RDS-J

NNL 18 33 KV S/Stn. Sehlang Bhagot DS ND231E 97.61 21.81 75.81 77.66 M/Garh City M/Garh RDS

NNL 19 33 KV S/Stn. Gudha Koka DS ND351A 39.95 9.03 30.92 77.39 M/Garh Kanina RDS

NNL 20 33 KV S/Stn. Majra Rewasa DS ND251G 92.24 21.21 71.03 77.01 M/Garh City M/Garh RDS-J

NNL 21 33 KV S/Stn. Satnali-Bass Patherwa DS ND291C 30.41 7.01 23.41 76.95 M/Garh S/U M/Garh RDS

NNL 22 33 KV S/Stn. Bawania Gagarwas DS ND221D 56.22 13.15 43.07 76.61 M/Garh City M/Garh RDS

NNL 23 33 KV S/Stn. Lehroda Dharson DS ND281D 125.25 30.44 94.81 75.70 Narnaul S/U Narnaul RDS

NNL 24 33 KV S/Stn. Lehroda Gulawala DS ND281C 80.11 19.98 60.14 75.07 Narnaul S/U Narnaul RDS

NNL 25 33 KV S/Stn. Khatoti Khorma DS ND012F 83.94 20.97 62.97 75.02 Narnaul S/U Narnaul RDS

NNL 26 33 KV S/Stn. Lehroda Barkoda DS ND281E 66.19 16.61 49.58 74.91 Narnaul S/U Narnaul RDS

NNL 27 33 KV S/Stn. Khatoti Kultajpur DS ND011C 81.24 20.92 60.32 74.25 Narnaul S/U Narnaul RDS

NNL 28 33 KV S/Stn. Nizampur Rambass-II DS ND021H 69.84 18.06 51.78 74.14 Narnaul S/U Narnaul RDS

NNL 2933 KV PUMP HOUSE MC-IV (CKT-

I M/GARH)Dhanonda DS ND154A 38.26 10.06 28.20 73.71 M/Garh Kanina RDS-J

NNL 30 33 KV S/Stn. Dhani Bathoda Dhani DS ND032E 58.79 15.63 43.16 73.41 Narnaul S/U Narnaul RDS

NNL 31 33 KV S/Stn. Dhani Bathoda Tehla DS ND032D 69.23 18.45 50.78 73.35 Narnaul S/U Narnaul RDS

NNL 32 132 KV S/Stn. Mundia-Khera Kothal DS NB051J 57.14 15.94 41.20 72.11 M/Garh S/U M/Garh RDS-J

NNL 33 33 KV S/Stn. SIHORE Jharli DS ND331B 35.91 10.59 25.31 70.50 M/Garh Kanina RDS

NNL 34 33 KV S/Stn. Satnali-Bass Dhana DS ND291F 39.70 11.87 27.83 70.11 M/Garh S/U M/Garh RDS

NNL 35 33 KV S/Stn. Sobhapur Navrangpura DS ND261C 39.63 11.98 27.65 69.77 Narnaul S/U Narnaul RDS

NNL 36 33 KV S/Stn. Budeen Nimbi DS ND271F 57.06 17.39 39.67 69.52 M/Garh S/U M/Garh RDS

NNL 37 33 KV S/Stn. Kheri Khudana-2 DS ND371E 45.06 13.95 31.11 69.04 M/Garh City M/Garh RDS

NNL 38 33 KV S/Stn. Dublana Atali DS ND061G 49.82 15.43 34.38 69.02 Narnaul S/U Narnaul RDS-J

NNL 39 33 KV S/Stn. Khatoti Dohar DS ND011B 49.82 15.46 34.36 68.97 Narnaul S/U Narnaul RDS

NNL 40 33 KV S/Stn. Bhojawas Gomla DS ND122D 54.79 17.27 37.52 68.49 M/Garh City M/Garh RDS-J

NNL 41 33 KV S/Stn. Bhojawas Chelawas DS ND121F 40.27 12.75 27.52 68.34 M/Garh Kanina RDS

NNL 42 33 KV S/Stn. Dholera Kamania DS ND241E 38.07 12.19 25.88 67.98 Narnaul N/Choudhary RDS

UNIT


% LINE

LOSSES

TOTAL OF 12 MONTHS


AM

E

OF

CIR

CL

E

TO

TA

L

NO

. O

F

FE

ED

ER


(FIGURES IN L.U.)

NAME OF OP

DIVISION

NAME OF OP SUB-

DIVISIONCATEGORY

NNL 43 33 KV S/Stn. Dhakora Amarpura DS ND382C 41.04 13.24 27.80 67.75 Narnaul N/Choudhary RDS


CHAUDHARYNangal Shalu DS NB021H 62.15 20.11 42.04 67.64 Narnaul N/Choudhary RDS

NNL 45 33 KV S/Stn. Zerpur Mandola DS ND131D 32.87 10.72 22.15 67.39 M/Garh S/U M/Garh RDS-J

NNL 46 33 KV S/Stn. Jant Noutana DS ND111F 91.40 30.20 61.20 66.96 M/Garh City M/Garh RDS

NNL 47 33 KV S/Stn. Dublana Khampura DS ND061H 34.20 11.57 22.63 66.17 Narnaul S/U Narnaul RDS

NNL 48 33 KV S/Stn. Nawan Nawan DS ND391A 1.25 0.43 0.83 65.95 M/Garh S/U M/Garh RDS

NNL 49 33 KV S/Stn. Bhilwara Tajpur DS ND311A 98.60 33.77 64.83 65.75 Narnaul Ateli RDS

NNL 50 33 KV S/Stn. Dholera Nayagaon DS ND241F 92.29 32.00 60.28 65.32 Narnaul N/Choudhary RDS

NNL 51 33 KV Ststn. Bhungarka Bhungarka DS ND321A 58.12 20.60 37.52 64.55 Narnaul N/Choudhary RDS-J

NNL 52 33 KV S/Stn. Kanti KANTI + Nawadi DS ND042D 96.81 34.72 62.09 64.13 Narnaul Ateli RDS

NNL 53 33 KV S/Stn. Nizampur Mokhuta DS ND021I 3.25 1.17 2.08 63.93 Narnaul S/U Narnaul RDS-J

NNL 54 33 KV S/Stn. Nizampur Bayal DS ND021J 38.79 14.14 24.65 63.55 Narnaul N/Choudhary RDS

NNL 55 33 KV S/Stn. SIHORE Sihore DS ND331A 26.26 9.60 16.66 63.46 M/Garh Kanina RDS


CHAUDHARYBudhwal DS NB023G 43.00 15.91 27.09 62.99 Narnaul N/Choudhary RDS

NNL 57 33 KV S/Stn. Kheri Kheri DS ND371A 29.37 10.90 18.47 62.90 M/Garh Kanina RDS-J

NNL 58 132 KV S/Stn. Ateli Silarpur DS NB013F 48.51 18.48 30.03 61.90 Narnaul Ateli RDS

NNL 59 33 KV S/Stn. Nangal Serohi Beri DS ND081A 75.80 29.29 46.51 61.36 M/Garh S/U M/Garh RDS-J

NNL 60 132 KV S/Stn. Ateli Bhori DS NB013G 51.82 20.70 31.12 60.05 Narnaul Ateli RDS-J

NNL 61 33 KV S/Stn. Bhojawas Partal DS ND121E 21.53 8.65 12.88 59.81 M/Garh Kanina RDS

NNL 62 33 KV S/Stn. Dublana Surani DS ND061I 68.20 30.29 37.91 55.58 Narnaul Ateli RDS-J

NNL 63 132 KV S/Stn. Mundia-Khera Kalwari DS NB051H 9.65 4.32 5.33 55.24 Narnaul Ateli RDS-J


CHAUDHARYKalba DS NB021G 20.51 9.44 11.06 53.95 Narnaul N/Choudhary RDS-J

NNL 65 33 KV S/Stn. Dhakora Gothary DS ND381B 33.33 15.37 17.96 53.89 Narnaul N/Choudhary RDS

NNL 66 33 KV S/Stn. Garhi Mahaser Mohlra DS ND051E 33.65 16.60 17.05 50.67 Narnaul Ateli RDS

RWR 1 33 KV S/Stn.Behrampur Surakhpur DS RD131A 71.85 10.57 61.28 85.29 Kosli Kosli RDS

RWR 2 33 KV S/Stn. Jharoda Lissan DS RD181I 33.98 5.11 28.87 84.97 Kosli Barouli RDS-J

RWR 3 33 KV S/Stn. Jharoda Dakhora DS RD181D 51.32 8.52 42.80 83.40 Kosli Kosli RDS

RWR 4 33 KV S/Stn. Bisowa Bharangi DS RD141H 85.51 14.32 71.19 83.26 Kosli Kosli RDS

RWR 5 132 KV S/Stn. Baroli Mayan DS RB011M 83.42 14.31 69.11 82.85 Kosli Barouli RDS

RWR 6 33 KV S/Stn. Khushpura Nangal Pathani DS RD151A 73.50 12.91 60.60 82.44 Kosli Kosli RDS

RWR 7 33 KV S/Stn. Bisowa Karoli DS RD141I 57.86 10.90 46.96 81.16 Kosli Kosli RDS-J

RWR 8 33 KV S/Stn. Bharawas Dharan DS RD031D 90.64 17.98 72.66 80.16 Dharuhera Ghothra RDS

RWR 9 132 KV S/Stn. Dahina Dhanibad DS RB021D 108.13 21.71 86.42 79.93 Kosli Barouli RDS

RWR 10 33 KV S/Stn. Jharoda Gamri DS RD181C 77.81 15.78 62.03 79.72 Kosli Kosli RDS

RWR 11 33 KV S/Stn. Bisowa Garhi DS RD141G 69.80 14.84 54.95 78.73 Kosli Kosli RDS

RWR 12 132 KV S/Stn. Bawal N.S.Pur DS RB041J 92.15 21.60 70.55 76.56 Dharuhera Bawal RDS-J

RWR 13 132 KV S/Stn. Baroli Ram puri DS RB011N 43.52 10.20 33.32 76.56 Kosli Barouli RDS-J

RWR 14 132 KV S/Stn.Gothra (Pali) Sundroj DS RB061K 83.42 19.90 63.52 76.15 Dharuhera Ghothra RDS

RWR 15 33 KV S/Stn. Bharawas Bithwana DS RD031G 79.02 19.09 59.93 75.84 Dharuhera Ghothra RDS

RWR 16 33KV S/Stn. Gurawara Gurawar DS RD211A 76.78 19.23 57.54 74.95 Kosli Palawas S/O RDS

RWR 17 33 KV S/Stn.Nangal Pathani Nangal Pathani-II DS RD171A 29.02 7.65 21.37 73.65 Kosli Kosli RDS-J

RWR 18 33 KV S/Stn. Khushpura Fatehpuri DS RD151G 25.75 6.80 18.96 73.61 Kosli Kosli RDS

RWR 19 132 KV S/Stn. Dahina Gothra DS RB021C 105.44 29.17 76.26 72.33 Kosli Barouli RDS

RWR 20 132 KV S/Stn. Bawal Dhani Ahir DS RB041K 62.84 17.43 45.41 72.27 Dharuhera Bawal RDS-J

RWR 21 132 KV S/Stn. Kosli Jhall DS RB031I 89.14 24.77 64.37 72.21 Kosli Kosli RDS

RWR 22 132 KV S/Stn. Bawal Keso Pur DS RB041I 103.52 29.09 74.42 71.89 Dharuhera Bawal RDS

RWR 23 132 KV S/Stn.Gothra (Pali) Bhandore DS RB063E 78.32 22.88 55.44 70.78 Dharuhera Ghothra RDS

RWR 24 132 KV S/Stn.Gothra (Pali) Thothwal DS RB061L 29.23 8.75 20.47 70.05 Dharuhera Ghothra RDS-J

RWR 25 132 KV S/Stn. Baroli Dehlawas DS RB011F 37.74 11.52 26.22 69.47 Kosli Barouli RDS-J

RWR 26 33 KV S/Stn. Bharawas Badhrana DS RD031E 35.01 10.87 24.14 68.95 Dharuhera Ghothra RDS-J

RWR 27 132 KV S/Stn.Gothra (Pali) Nandha DS RB061G 85.83 26.76 59.07 68.83 Dharuhera Ghothra RDS

RWR 28 132 KV S/Stn. Bawal Kasola DS RB043I 84.75 26.76 57.99 68.43 Dharuhera Bawal RDS

RWR 29 132 KV S/Stn. Bawal Panwar DS RB043A 91.43 28.99 62.44 68.30 Dharuhera Bawal RDS

RWR 30 33 KV S/Stn.Behrampur Rattanthal DS RD131D 68.54 22.43 46.11 67.27 Kosli Kosli RDS

RWR 3133 KV PUMP HOUSE JC-I

(Gudiyani)Bhuriawas DS RD121D 39.25 12.85 26.40 67.27 Kosli Kosli RDS

RWR 32 33 KV S/Stn.Nangal Pathani Bhotwas Bhondu DS RD171F 21.85 7.17 14.68 67.18 Kosli Kosli RDS-J

RWR 33 33 KV S/STN. KHARKHARA KHARKHARA DS RD321E 3.20 1.16 2.04 63.63 Dharuhera Dharuhera RDS

UNIT


% LINE

LOSSES

TOTAL OF 12 MONTHS


AM

E

OF

CIR

CL

E

TO

TA

L

NO

. O

F

FE

ED

ER


(FIGURES IN L.U.)

NAME OF OP

DIVISION

NAME OF OP SUB-

DIVISIONCATEGORY

RWR 34 132 KV S/Stn. Baroli Mundi DS RB011H 70.34 25.98 44.36 63.07 Kosli Barouli RDS

RWR 35 33 KV S/Stn. Khol Mandola/Bohka DS RD081D 37.51 14.18 23.33 62.20 Kosli Barouli RDS

RWR 36 66 KV S/Stn. Baliyar Kalan Hansaka DS RC021A 60.48 23.00 37.48 61.97 Dharuhera Dharuhera RDS

RWR 37 132 KV S/Stn. Kosli Gudiyani DS RB031B 159.31 61.34 97.97 61.50 Kosli Kosli RDS

RWR 38 66 KV S/Stn. Baliyar Kalan Majra Sheoraj DS RC021B 57.67 22.93 34.74 60.24 Rewari S/U Rewari RDS

RWR 39 33 KV S/Stn. JATUSANA J C - II Murlipur-II DS RD021J 103.39 41.45 61.94 59.91 Kosli Palawas S/O RDS

RWR 40 33 KV S/Stn. Khol Dhani Kolana DS RD081E 13.45 5.42 8.03 59.72 Kosli Barouli RDS-J

RWR 41 33 KV S/Stn. Kakoria Jhanti DS RD191C 30.85 12.45 18.40 59.65 Rewari S/U Rewari RDS

RWR 42 33 KV S/Stn. Palhawas Karawara DS RD201F 69.48 28.60 40.88 58.84 Kosli Palawas S/O RDS

RWR 43 33 KV S/Stn.Kaluwas Kaluwas DS RD051G 16.22 6.68 9.54 58.81 Rewari S/U Rewari RDS

RWR 44 33 KV S/Stn. Kakoria Jat Bhurathal DS RD191D 48.89 20.31 28.59 58.47 Rewari S/U Rewari RDS

RWR 45 33 KV S/Stn. Palhawas Noorgarh DS RD201G 40.81 17.28 23.53 57.65 Kosli Palawas S/O RDS-J

RWR 46 33 KV S/Stn.Kaluwas Haluhera DS RD051E 49.39 21.34 28.05 56.80 Rewari S/U Rewari RDS

RWR 47 66 KV S/Stn. Dharuhera GOYAL COLONY DS RC01M1I 41.79 18.25 23.54 56.33 Dharuhera Dharuhera RDS

RWR 48 132 KV S/Stn. Bawal M.P. Basai DS RB043G 82.76 36.45 46.31 55.96 Dharuhera Bawal RDS-J

RWR 49 33 KV S/Stn. Palhawas Mastapur DS RD201E 51.52 22.91 28.62 55.54 Kosli Palawas S/O RDS-J

RWR 50 220 KV S/Stn. Rewari Ghasera DS RA01J3F 86.92 38.77 48.15 55.40 Rewari S/U Rewari RDS-J

RWR 51 33 KV S/Stn. J C - IV Ladhuwas Gujjar DS RD061A 79.59 35.51 44.09 55.39 Rewari S/U Rewari RDS

RWR 52 132 KV S/Stn. Baroli Kumrodha DS RB011G 50.54 22.58 27.96 55.31 Kosli Barouli RDS

RWR 53 132 KV S/Stn. Bawal Raipur DS RB043J 28.90 13.14 15.76 54.52 Dharuhera Bawal RDS

RWR 54 132 KV S/Stn. Kosli Kosli DS RB031C 109.01 49.65 59.36 54.46 Kosli Kosli RDS

RWR 55 33 KV S/Stn. Bisowa Bisowa DS RD141F 10.92 5.06 5.86 53.68 Kosli Kosli RDS

RWR 56 33KV S/Stn. Berli Khurd Musepur-II DS RD161C 58.08 27.13 30.95 53.29 Rewari S/U Rewari RDS-J

RWR 57 33 KV S/Stn. Jonawas Rojka DS RD041L 78.05 36.90 41.15 52.72 Dharuhera Dharuhera RDS-J

RWR 58 33 KV S/Stn. Khol Khol DS RD081C 15.49 7.32 8.16 52.71 Kosli Barouli RDS-J

RWR 59 220 KV S/Stn. Rewari Jant DS RA011D 14.98 7.14 7.84 52.32 Rewari S/U Rewari RDS

RWR 60 132 KV S/Stn.Gothra (Pali) Pali DS RB063F 32.54 15.55 16.98 52.20 Dharuhera Ghothra RDS-J

RWR 61 33 KV S/Stn.Nangal Pathani Murlipur DS RD171B 20.46 10.01 10.45 51.07 Kosli Kosli RDS-J

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Filed by Dakshin Haryana Bijli Vitran Nigam Limited Hisar FY...and Annual Revenue Requirement for FY 2018-19 by Dakshin Haryana Bijli Vitaran Nigam Limited under HERC (Terms and Conditions