REVISED BUSINESS PLAN FOR MYT CONTROL PERIOD FY 2014-15 … FY 2014-15 TO FY 2018-19 . HPSEBL...

Submitted to

HIMACHAL PRADESH ELECTRICITY REGULATORY

COMMISSION, SHIMLA

By

HIMACHAL PRADESH STATE ELECTRICITY BOARD

LIMITED, SHIMLA

February, 2014

REVISED BUSINESS PLAN

FOR MYT CONTROL PERIOD

FY 2014-15 TO FY 2018-19

HPSEBL Business Plan – MYT Control Period: FY 2014-15 to FY 2018-19

Nov, 2013 ii

TABLE OF CONTENTS

TABLE OF CONTENTS .................................................................................................................... ii

LIST OF TABLES ........................................................................................................................... iv

LIST OF FIGURES ........................................................................................................................... v

LIST OF ABBREVIATIONS ............................................................................................................... 1

1. INTRODUCTION ......................................................................................................... 3

1.1. Background .............................................................................................................. 3

1.2. Objective of Business Plan ....................................................................................... 4

2. BRIEF ABOUT HPSEBL ................................................................................................. 5

2.1. Mission of HPSEBL ................................................................................................... 5

2.2. Area served .............................................................................................................. 5

2.3. Organisation structure: Roles & Responsibilities .................................................... 6

2.4. Human resources ..................................................................................................... 7

2.5. IT & Other Initiatives................................................................................................ 8

2.6. Activities related to Consumer Service ................................................................. 12

2.7. Rajiv Gandhi Grameen Vidyutikaran Yojana (RGGVY) ........................................... 12

2.8. R-APDRP (Part-B) ................................................................................................... 13

2.9. Financial Restructuring Plan .................................................................................. 13

3. SWOT ANALYSIS ....................................................................................................... 14

4. SALES ...................................................................................................................... 17

4.1. Load Growth .......................................................................................................... 17

4.2. Consumer Growth ................................................................................................. 18

4.3. Energy Sales Growth .............................................................................................. 19

5. OWN GENERATION .................................................................................................. 21

5.1. Generation from own generating stations of HPSEBL........................................... 21

6. POWER PURCHASE PLAN .......................................................................................... 24

6.1. Quantum of Power Purchase ................................................................................ 24

6.2. Power purchase from other generating stations .................................................. 24

6.3. Power Purchase Projection Methodology ............................................................. 25

7. T & D LOSS TRAJECTORIES & ENERGY BALANCE ......................................................... 36

7.1. Transmission and Distribution Losses ................................................................... 36

8. TRANSMISSION CHARGES......................................................................................... 38


Nov, 2013 iii

9. CAPITAL INVESTMENT PLAN ..................................................................................... 40

9.1. Capital Investment plan for Distribution schemes ................................................ 40

9.2. Capital investment plan for Generation Schemes ................................................. 43

9.3. Phasing of capital expenditure .............................................................................. 45

10. ESTIMATION OF ARR ................................................................................................ 47

10.1. Operation & Maintenance Expenses ..................................................................... 47

10.2. Depreciation .......................................................................................................... 52

10.3. Interest & Finance Charges ................................................................................... 53

10.4. Provision for bad and doubtful debts .................................................................... 55

10.5. Non tariff income ................................................................................................... 55

10.6. Return on equity .................................................................................................... 57

10.7. ARR summary ........................................................................................................ 57


Nov, 2013 iv

LIST OF TABLES

Table 1: Hydro generating plants of HPSEBL ............................................................................. 6

Table 2: SWOT Analysis ............................................................................................................ 14

Table 3: Past years’ load growth .............................................................................................. 17

Table 4: Projected load growth during Control Period (FY 2014-15 to FY 2018-19) ............... 17

Table 5: Past years’ consumer growth ..................................................................................... 18

Table 6: Projected consumer growth during Control Period (FY 2014-15 to FY 2018-19) ...... 19

Table 7: Past years’ growth energy sales growth (MUs) ......................................................... 19

Table 8: CAGR for past years .................................................................................................... 20

Table 9: Projected energy sales’ growth during Control Period (FY 2014-15 to FY 2018-19) . 20

Table 10: Past years’ net generation from own plants ............................................................ 21

Table 11: Projected own generation during Control Period (FY 2014-15 to FY 2018-19) ....... 22

Table 12: Total Power Purchase Cost from Own Generation .................................................. 23

Table 13: Power Purchase from Other Key Generating Stations ............................................ 24

Table 14: Power Procurement from GoHP (Free Power Allocation of GoHP in MUs) ............ 25

Table 15: Total Power Purchase Cost from GoHP ................................................................... 26

Table 16: Power procurement from NTPC owned plants ....................................................... 27

Table 17: Total Power Purchase Cost from NTPC Stations ...................................................... 28

Table 18: Power procurement from NPCIL plants .................................................................. 29

Table 19: Total Power Purchase Cost from NPCIL Stations ..................................................... 29

Table 20: Power Procurement from NHPC plants .................................................................. 30

Table 21: Total Power Purchase Cost from NHPC Stations ..................................................... 30

Table 22: Power procurement from THDC plants .................................................................. 31

Table 23: Total Power Purchase Cost from THDC Stations ...................................................... 31

Table 24: Power procurement from SJVN Stations ................................................................. 31

Table 25: Total Power Purchase Cost from SJVN ..................................................................... 32

Table 26: Power procurement from shared stations .............................................................. 32

Table 27: Total Power Purchase Cost from Other CGS and shared stations ........................... 32

Table 28: Additional Solar Power Requirement ...................................................................... 33

Table 29: Power procurement from other stations ................................................................. 33

Table 30: Total power purchase cost from other stations ...................................................... 34

Table 31: Power Purchase (MUs) from other sources ............................................................. 34

Table 32: Total Power Purchase Cost from other sources ...................................................... 34

Table 33: Overall Power Purchase (MUs) ................................................................................ 35

Table 34: Total Power Purchase Cost ...................................................................................... 35

Table 35: Average Cost of Power Procurement (INR/ Unit) .................................................... 35

Table 36: Proposed T&D Loss Trajectory ................................................................................. 37

Table 37: Energy Balance ......................................................................................................... 37

Table 38: Summary of Transmission Charges (INR Cr) ............................................................ 38

Table 39: Scheme Wise CAPEX Plan ......................................................................................... 44


Nov, 2013 v

Table 40: CAPEX summary ....................................................................................................... 45

Table 41: Funding summary ..................................................................................................... 46

Table 42: K factor calculation................................................................................................... 48

Table 43: WPI ........................................................................................................................... 48

Table 44: R&M Expenses ......................................................................................................... 48

Table 45: CPI............................................................................................................................. 49

Table 46: Growth factor for employee costs ........................................................................... 50

Table 47: Employee Expenses for 3rd Control Period (Rs. Crs) ............................................... 50

Table 48: A&G norms ............................................................................................................... 51

Table 49: Projections for applying A&G norms ....................................................................... 51

Table 50: A&G Expenses for 3rd Control Period (Rs. Crs) ........................................................ 51

Table 51: Asset details for depreciation calculations .............................................................. 52

Table 52: Depreciation for 3rd Control Period (Rs. Crs) .......................................................... 53

Table 53: Interest on new & existing loans.............................................................................. 53

Table 54: Interest on working capital ...................................................................................... 54

Table 55: Total interest and finance charges ........................................................................... 54

Table 56: Provision for Bad and Doubtful Debt for last 3 years (Rs. Crs) ................................ 55

Table 57: Provision for Bad and Doubtful Debt for 3rd Control Period (Rs. Crs) .................... 55

Table 58: Non Tariff Income for 3rd Control Period (Rs. Crs) .................................................. 56

Table 59: Return on equity ...................................................................................................... 57

Table 60: Annual Revenue Requirement for 3rd Control Period (Rs. Crs)................................ 58

Table 61: Wheeling ARR for 3rd Control Period (Rs. Crs) ......................................................... 58

Table 62: Retail Supply ARR for 3rd Control Period (Rs. Crs)................................................... 59

LIST OF FIGURES

Figure 1: District map of HP ....................................................................................................... 5

Figure 2: Organisation structure of HPSEBL............................................................................... 7


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LIST OF ABBREVIATIONS

Sr. No Abbreviations Descriptions

1. A&G Administrative and General

2. AC Auxiliary Consumption

3. APR Annual Performance Review

4. ARR Aggregate Revenue Requirement

5. AS Accounting Standard

6. CAGR Compound Annual Growth Rate

7. CAPEX Capital Expenditure

8. CERC Central Electricity Regulatory Commission

9. CGS Central Generating Station

10. CoS Cost of Supply/ Service

11. CPPs Captive Power Plants

12. Crs Crores

13. CWIP Capital Work in Progress

14. DF Distribution Franchisee

15. Discom Distribution Companies

16. DPS Delayed Payment Surcharge

17. DS Domestic Service

18. DSM Demand Side Management

19. DTC Distribution Transformer

20. EA/The Act The Electricity Act 2003

21. F&A Finance & Accounts

22. FY Financial Year

23. GFA Gross Fixed Assets

24. G.O. Government Order

25. GoI Government of India

26. GoHP Government of Himachal Pradesh

27. HP Himachal Pradesh

28. HR Human Resource

29. HRA House Rent Allowance

30. HT High Tension

31. HEP Hydro Electric Power

32. IPP Independent Power Producers

33. KV Kilo Volt

34. kVA Kilo Volt Ampere

35. kVAh Kilo Volt Ampere Hour

36. kW Kilo Watt


Nov, 2013 Page | 2

Sr. No Abbreviations Descriptions

37. kWh Kilo Watt Hour

38. LF Load Factor

39. LT Low Tension

40. MD Maximum Demand

41. MOD Merit Order Despatch

42. MoP Ministry of Power

43. MOU Memorandum of Understanding

44. MU Million Units (Million kWh)

45. MVA Mega Volt Ampere

46. MW Mega Watt

47. MYT Multi Year Tariff

48. NEP National Electricity Policy

49. NTP National Tariff Policy

50. NTPC National Thermal Power Corporation

51. O&M Operation & Maintenance

52. PAF Plant Availability Factor

53. PF Provident Fund

54. PFC Power finance Corporation

55. PLF Plant Load Factor

56. PLR Prime Lending Rate

57. PPA Power Purchase Agreement

58. PSD Power Service Division

59. REC Rural Electrification Corporation

60. R&M Repair and Maintenance

61. ROE Return on Equity

62. RPO Renewable Purchase Obligation

63. Rs Rupees

64. SBI State Bank of India

65. SLM Straight Line Method

66. SHR Station Heat Rate

67. T&D Transmission and Distribution

68. HPSEBL Himachal Pradesh State Electricity Board Limited

69. HPERC Himachal Pradesh Electricity Regulatory Commission

70. w.e.f With effect from

71. Y-o-Y Year on Year


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1. INTRODUCTION

1.1. Background

1.1.1 Himachal Pradesh is a mountainous state having altitudes ranging from 350 mtrs

to 6,975 mtrs with climate conditions varying from semi-tropical to semi-arctic.

The total population of Himachal Pradesh as per 2011 census was 68,56,509 with

population density being 123 persons per sq. km. Focused work for putting

together a strong electrical network in the state began in August, 1953 under the

Public Works Department, when the first electrical division was established.

Subsequently a department of M.P.P & Power was formed in April, 1964.

1.1.2 The Himachal Pradesh State Electricity Board was constituted on 1st September,

1971 in accordance with the provisions of Electricity Supply Act (1948). It

functioned as Distribution, Generation as well as Transmission licensee for the

state of Himachal Pradesh up to 10th June, 2010, when the Government of

Himachal Pradesh, in exercise of the power conferred to it, by Section 131 (2),

132, 133 and other applicable provisions of the Electricity Act 2003, vide the

‘Himachal Pradesh Power Sector Reforms transfer Scheme, 2010’ transferred the

functions of generation, distribution and trading of electricity to Himachal

Pradesh State Electricity Board Limited (HPSEBL).

1.1.3 Himachal Pradesh State Electricity Board Limited (HPSEBL), having its registered

office at Vidyut Bhawan, Shimla, is responsible for supply of uninterrupted &

quality power to all categories of consumers in Himachal Pradesh at the most

seconomical rates.

1.1.4 The key duties being discharged by HPSEBL are:

Laying and operating of such electric line, sub-station and electrical plant that

is primarily maintained for the purpose of distributing electricity in the area of

supply of ‘HPSEB Ltd.’, notwithstanding that such line, sub-station or electrical

plant are high pressure cables or overhead lines or associated with such high

pressure cables or overhead lines; or used incidentally for the purpose of

transmitting electricity for others, in accordance with Electricity Act. 2003 or

the Rules framed there under.

Operating and maintaining the existing generating stations and shall establish,

operate and maintain generating stations, tie-lines, sub-stations and

dedicated transmission lines connected there with as per the provisions of the

Act and the Rules framed there under

Arranging, in-coordination with the Generating Company(ies) operating in or


Nov, 2013 Page | 4

outside the State, for the supply of electricity required within the State and for

the distribution of the same in the most economical and efficient manner;

Supplying electricity, as soon as practicable to any person requiring such

supply, within its competency to do so under the said Act;

Preparing and carrying out schemes for distribution and generally for

promoting the use of electricity within the State.

1.2. Objective of Business Plan

1.2.1 The Himachal Pradesh Electricity Regulatory Commission (HPERC), in exercise of

the powers conferred on it by section 181 of the Electricity Act 2003 (Act 36 of

2003) and all other powers, has issued HPERC (Terms and Conditions for

Determination of Wheeling Tariff and Retail Supply Tariff) Regulations, 2011 along

with Amendment 1, 2012 and Amendment 2, 2013, and HPERC (Terms and

Conditions for Determination of Hydro Generation Tariff) Regulations, 2011 along

with Amendment 1, 2011 and Amendment 2, 2013, hereinafter referred to as

“MYT Regulations”.

1.2.2 As per the Regulations, Business plan comprising of Generation business (with

plant-wise details) for the entire control period and Distribution business

containing details regarding sales/ demand forecast, T&D loss reduction

trajectory, power procurement plan, capital investment plan, financing structure,

O&M cost estimates, etc. for the control period is required to be filed before the

Hon’ble Commission as part of the Tariff Filing before the beginning of the Control

Period.

1.2.3 Accordingly, HPSEBL had filed the MYT Petition and Business Plan along with the

requisite fee on 30/11/2013 bearing No. 141/2013. However, in response to

Commission’s letter No. HPERC/ MYT3/ HPSEBL/ 2013-14-2571, dated

05/12/2013, HPSEBL is hereby filing the revised Business Plan for 3rd Control

Period (FY 2014-15 to FY 2018-19) based on the available data for the FY 2013-14

and provisional data of previous 3 years.

1.2.4 HPSEBL has prepared the Business Plan taking cognizance of the existing internal

factors and external business environment affecting the business. HPSEBL submits

that the Business plan being a dynamic document may need to be updated at

periodic intervals taking into account the changes in the internal and external

environment and these changes would be intimated to the Hon’ble Commission

from time to time.


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2. BRIEF ABOUT HPSEBL

2.1. Mission of HPSEBL

2.2. Area served

2.2.1 The total area of Himachal Pradesh state is 55,673 Sq. Km. HPSEBL is the sole

distribution licensee of the state and caters to entire HP. It serves its consumers in

one of the most difficult and varying terrains when compared to other states of

India.

2.2.2 HPSEBL’s distribution operations are divided into three operations zones viz.

North, South and Central for ensuring efficient customer services and improved

management. The zones are further divided into 12 operation circles which cover

the 12 districts of the state.

Figure 1: District map of HP

Courtesy: www.himachal.gov.in

Uninterrupted, Reliable and Quality Power Supply to all our Consumers on

competitive rates

http://www.himachal.gov.in/


Nov, 2013 Page | 6

2.2.3 Generation

2.2.3.1 In addition to supply of electricity to the end consumers of the state, HPSEBL also

generates hydro – electricity via its 21 plants of varying MW capacity. The total

installed capacity of these plants in FY 2013-14 is 477.45 MW.

2.2.3.2 The following table gives the list of the 21 hydro-generating stations being

operated by HPSEBL along with their installed capacities

Table 1: Hydro generating plants of HPSEBL

Name of Station Installed Capacity

(MW) Year of

commissioning

Giri 60.00 1978

Andhra 16.95 1987

Gumma 3.00 2000

Bhaba 120.00 1989

Nogli 2.50 1975

Ghanvi 22.50 2000

Bhaba Aug. 4.50 2000

Chaba 1.75 1913

Bassi 66.00 1970

Binwa 6.00 1984

Gaj 10.50 1996

Baner 12.00 1996

Khauli 12.00 2007

Rukti 1.50 1979

Rong-Tong 2.00 1987

Chamba 0.45 1938

Sal-II 2.00 1999

Killar 0.30 1995

Holi 3.00 2004

Thirot 4.50 1995

Larji 126.00 2007

Total capacity 477.45

2.3. Organisation structure: Roles & Responsibilities

2.3.1 The Chairman of HPSEBL is the official head of HPSEBL, while day to day

management is handled by the Managing Director. The Managing Director is

supported by five Directors – Civil, Technical, Operations, Personnel and F&A,

along with one Executive Director – Personnel and one Chief engineer – Planning

& Monitoring.


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2.3.2 The Directors are in turn supported by an efficient team of Chief Engineers,

Superintending Engineers, Executive Engineers, and so on.

Figure 2: Organisation structure of HPSEBL

2.4. Human resources

2.4.1 HR Department of HPSEBL focuses on work in the areas of manpower

management, customer relations and skills development. It strongly believes in

training employees for better development of employees and thereby prepared

structural need based training calendar for its employees.

2.4.2 The total sanctioned strength for 2012-13 was 24909 out of which 20,861 was the

on-ground employee strength. There has been a growth in the employee strength

for HPSEBL in 2013-14 and the total strength now stands at 21,367 which include

the sanctioned new recruitment of 616 posts.

2.4.3 There is a need to ascertain the training of the existing human resource and to

identify their core competencies with an aim to enhance their skills and finally

Chairman

Managing Director

Director (Civil)

CE (PCA)

CE (I & P)

Director (Technical)

CE (SO&P)

CE (Generation)

CE (ES)

Director (Operations)

CE (OP/South)

CE (OP/North)

CE (OP/Central)

CE (Comm)

CE (MM)

Director (F&A)

CAO

Director (Personnel)

ED (Personnel)

CE (P&M)

SE (P&M) Civil

SE (P&M) Electrical


Nov, 2013 Page | 8

place them in appropriate job positions. HPSEBL endeavours to conduct training

at periodic intervals for capacity building of its manpower.

2.4.4 Recruitment Policy: For the purpose of recruitment, HPSEBL follows a broad

classification of Services into Technical and Non-Technical Staff. The Technical

Staff comprises of engineers, supervisors and technicians. The rest of the staff

forms the Non-Technical staff, viz. accounts, HR, security etc.

2.4.4.1 The appointment for a post, it is either made by promotion or by direct

recruitment. HPSEBL has chalked out its future manpower requirements for

expansion projected and it is proposed that recruitments to the tune of 616 posts

across technical and non-technical categories shall be carried out during 2013-14

and 2014-15. The future projections for recruitment are under consideration.

2.4.5 Health and Safety Management:

2.4.5.1 HPSEBL is of the firm belief that the health and safety of the employees is of

paramount importance. HPSEBLis committed to identifying and assessing all types

of occupational health and safety risk and takes proactive steps to reduce the

significant risk in turn to reduce the occurrences of accidents. The measures taken

are listed under:

One well established dispensary is situated in the campus of HPSEBL Head

office, Shimla for the employees of HPSEBL.

Efforts are being made to create awareness of occupational health and safety

in all employees, contractors and contract labour and training them

adequately for safe working practices.

2.5. IT & Other Initiatives

2.5.1 At the utility level, many IT initiatives are under implementation in HPSEBL which

focus on consumer service and better governance. Various processes are

identified for which IT applications are developed and automation of the process

is undertaken. The automated processes are deployed in modular form as and

when the system is tested and stabilized. The various IT initiatives are discussed in

the following paras.

2.5.2 In-house Activities


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2.5.2.1 Official Website of HPSEBL

The HPSEBL has hosted its official website (www.hpseb.com) and most of the

important information relating to public and official use has been put on the site.

The some of the important information are as under:

Application Forms for new connections.

Current tariff rates of all categories of Consumers.

Link for Online Bill Payment of bills.

Toll free number for registering of complaints.

Tenders notifications.

Material Specifications.

Statistical Data.

Contact numbers of officers.

Beside these, other useful information pertaining to consumers, employees &

suppliers are also hosted on the website.

2.5.2.2 Employee Information System

Web based system is in place for displaying the Personal, Posting, Promotion

Information of Gazetted Employees. The link for the same is available in the

Employees Corner of the website of HPSEBL.

2.5.3 Outsourced Activities:

2.5.3.1 R-APDRP (Part-A):

The Ministry of Power has sanctioned DPR’s for 14 eligible towns under Part-‘A’ of

the R-APDRP scheme for HPSEBL. The objective of the program is reduction of

Aggregate Technical and Commercial (AT&C) losses to 15% in project areas. The

total project cost for Part-A under R-APDRP is Rs. 93.62 Cr.:

a) Meter Data Acquisition System (MDAS);

b) Energy Audit(EA);

c) Identity & Access Management System is proposed at data centre level;

d) Management Information System (MIS) containing DW & BI tools is

proposed at data centre level;

e) Enterprise Management System (EMS) and Network Management System

(NMS) which is part of hardware, is proposed at data center level;

Data Center at Shimla is functional. Modems in 14 towns are already installed.

Integration of Legacy Application i.e. GIS, Computerized Billing etc. with R-APDRP

modules has been completed. 13 towns namely Bilaspur, Kullu, Sundernagar,

Chamba, Hamirpur, Una, Solan, Yol, Paonta, Dharamshala ,Baddi and Mandi have

been declared Go-Live. Shimla is planned to be declared during December 2013.


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2.5.3.2 ERP/SAP

The work of implementation of ERP (SAP) was allotted to M/s TCS In this project;

the following modules of ERP (SAP) are to be implemented in HPSEBL.

1. Financial Management and Accounting

2. Human Resource Management including payroll

3. Project Management

4. Materials Management

5. Maintenance Management

6. Availability Based Tariff and

A Dash Board for Senior Management for MIS purpose shall also be available. The

total cost of the project is approximately Rs. 45.70 Cr. 1st Phase covering Head

Office and Operation Circle Shimla except Theog and Sunni Electrical Divisions

have been declared “Go Live” in the month of March, 2013. 2nd Phase covers the

entire Board and left out modules, which is expected to go live in a phased

manner till March, 2014.

2.5.3.3 Computerized Billing and Energy Accounting Package

Computerized Billing and Energy Accounting Package (IT Package) was

implemented under the ‘Accelerated Power Development and Reform Program

(APDRP)’ launched by Ministry of Power (MOP). Under this project, the activities

of the operation sub-divisions are computerized through functionalities such as

Pre-billing Activities, Billing Activities, Post Billing Activities, Legal & Vigilance

Activities, Store Management at sub-division level, Customer Relationship

Management, Electrical Network Management & Energy Accounting/Auditing and

Management Information System (MIS). The award was placed on M/S HCL

Infosystems, Noida for an amount Rs. 6.20 Cr. The project has been implemented

in 132 subdivisions of 27 divisions and 12 circles covering more than 12 lakh

consumers. Centralized data center and call center has also been established at

Vidyut Bhawan, Shimla.

2.5.3.4 GIS/GPS Based asset Mapping including Consumer Indexing and Valuation of

Assets of HPSEB Ltd.

HPSEBL has decided to carry out GIS/GPS based asset mapping including

consumer indexing and valuation of assets for the whole HPSEB, which will be

used as the base for computerization of billing, energy accounting, electrical

network management and to create fixed assets registers with its present value

for its three wings namely Generation, Transmission and Distribution after proper

reconciliation with latest balance sheet of the Board. Pilot project has since been

completed for operation circle Shimla. For remaining 11 circles, field related


Nov, 2013 Page | 11

activities of the project have been completed and approval of data by HPSEBL is in

progress. Valuation report for all circles shall be finalized by March 2014.

Updation of GIS/GPS data in 14 R-APDRP towns has been awarded for next five

years as per the requirement of R-APDRP project.

2.5.4 New IT Initiatives:

2.5.4.1 Smart Grid Pilot project at Kala Amb in Himachal Pradesh

HPSEB Ltd. has prepared a pilot project worth Rs. 27 Crores. The Govt. of India has

approved the DPR for Rs. 18.11 Crores out of which Ministry of Power shall bear

Rs. 8.92 Crores and the balance funding has to be arranged by HPSEB Ltd. through

financial institutions like REC. HPSEBL proposes to implement Smart Grid Pilot in

Kala Amb with a payback period of 3 years by deployment of Smart Grid

Technologies to improve the system performance by reduction in peak power by

6 MVA, reduce outages, improve consumer engagement and satisfaction and

improve HPSEBL’s overall financial performance by implementing AMI, DSM and

GIS based outage management system.

2.5.4.2 Wi-Fi facility in Vidyut Bhawan Campus

Wi-Fi facility is proposed to be installed in the Vidyut Bhawan Campus during

2014-15 to resolve the network connectivity issues in the campus being faced in

implementation of various IT initiatives.

2.5.4.3 Expansion of AMR

It is proposed to cover all the consumers above 50 KW which comes to 32,000

consumers under the AMR in a phased manner across the state utilizing the

existing infrastructure developed under R-APDRP.

2.5.4.4 Expansion of Computerized billing

It is proposed to start computerized billing in 61 subdivisions using standard

platform during 2014-15. After stabilization and analyzing the performance it is

proposed to shift the billing of 132 subdivisions where computerized billing has

already been implemented to this platform in a phased manner.

2.5.4.5 GIS/GPS data updation in Non R-APDRP area

Updation of GIS/GPS data in non R-APDRP area of the state is proposed to be

done and utilize the same in various electrical network applications.

2.5.4.6 SCADA/DMS

A pilot project for the control and monitoring of all un-manned 33kV and above

Substations being commissioned in the State is envisaged to be setup at the DR

Center Poanta.


Nov, 2013 Page | 12

2.5.4.7 R-APDRP next phase

The MoP is considering extension of R-APDRP program to towns with population

greater than 5000 in the next phase of this program under which 16 new towns

are proposed to be covered commencing from 2015-16 onwards

2.6. Activities related to Consumer Service

2.6.1 HPSEBL has established a customer care centre for telephonic booking of

customer complaints. It is 24x7 call centre and works for the following objectives:

improving consumer services;

minimizing the fault detection and rectification time by monitoring the

occurrence;

improving performance of service by analyzing outage data and computing

reliability of network;

achieving Service Level Guarantees, improving Service Level Performance and

fulfilling Service Level Expectations of the customer.

2.6.2 HPSEBL has also been maintaining the Standards of Performance as per HPERC

(Distribution Performance Standards) Regulations ensuring complete satisfaction

to the consumer.

2.7. Rajiv Gandhi Grameen Vidyutikaran Yojana (RGGVY)

2.7.1 Against the sanctioned amount of Rs. 341.86 crores, the Govt. of India has

released an amount of Rs. 291.09 crores and HPSEB Ltd. has incurred an

expenditure of about Rs. 296 crores. Only 5% work is remaining in remote and

tribal areas of the state. In all other areas the work is complete.

2.7.2 RGGVY schemes envisaged under 12th Plan coverage of villages and habitations

with population above 50 are being considered. Hence it is pertinent to bring out

that in Himachal Pradesh number of villages as per 2011 census are 17881 out of

which 13407 villages have population above 100 and there are 4474 villages

which are having population below 100. HP being a special category State, the

condition of coverage for villages and habitations has been relaxed which are

having population above 50.

The position of electrification of villages under RGGVY is as under:

Un-electrified villages to be taken for electrification

91

Total Villages electrified upto October, 2013 83

Total Villages to be electrified under RGGVY Programme

8


Nov, 2013 Page | 13

2.8. R-APDRP (Part-B)

2.8.1 R-APDRP (Part B) scheme has been sanctioned for 14 towns in HP, having

population 10,000 and above as per 2001 census, for an amount of Rs. 338.97

crores. An expenditure of Rs. 54.17 Crores has been incurred in the 14 towns of

HP as on 31.10.2013. The works are progressing well.

2.9. Financial Restructuring Plan

2.9.1 The Ministry of Power, Government of India vide notification dated 5th Oct, 2012

has notified Financial Restructuring Scheme for DISCOMs. The State DISCOM i.e

HPSEB Ltd. has prepared draft Financial Restructuring Plan in consultation with

State Bank of India, the nodal bank on the basis of GoI notification and submitted

the Plan to Himachal Pradesh State Electricity Regulatory Commission and

Government of Himachal Pradesh. The HPERC has given In-Principle approval to

the draft Plan of HPSEB Ltd.

2.9.2 As per Scheme, the eligible amount is Rs. 1398.22 Crore plus Rs. 352.38 cr.

(Liability for Purchase of Power as on 31/03/2012). HPSEB Limited will float the

bonds amounting to Rs 700.00 Crore and balance is to be serviced through

Financial Restructuring Plan (FRP) submitted to nodal bank.


Nov, 2013 Page | 14

3. SWOT ANALYSIS

3.1.1 As part of the development of a strategic plan for any organization, it is necessary

to understand the inherent competitive advantage of the company as well as the

risk surrounding its business environment. Like any other businesses, it is very

important for HPSEBL to evaluate the environment – both internal and external

while charting out its growth path. The aim of a SWOT analysis is to identify the

key internal and external factors that are important for achieving the objectives of

the company.

3.1.2 The SWOT analysis is a strategic planning technique used to assess the internal

and external environment in which the company operates and competes. These

come from within the company's unique value chain. The information being used

for the SWOT analysis is grouped into two main categories:

Internal factors – The strengths and weaknesses internal to the organization;

External factors – The opportunities and threats presented by the external

environment to the organization;

3.1.3 This section provides the analysis of the strengths, weaknesses, opportunities and

threats as perceived by HPSEBL. These are summarized in the following table:

Table 2: SWOT Analysis

Helpful

In achieving the objective

Harmful

In achieving the objective

Inte

rnal

A

ttri

bu

tes

of

the

Org

anis

atio

n

STRENGTHS

Quality Power Supply

Lower Losses

Efficient Customer Service

Setting up of CGRF

WEAKNESS

Ageing Distribution Network

Uncertainties of Hydro

generation

Ageing Manpower

Exte

rnal

A

ttri

bu

tes

of

the

Envi

ron

men

t

OPPORTUNITIES

Business Growth due to

Improved Life Style

THREATS

Increase in Coal Prices

Increasing Avg CoS – ARR Gap


Nov, 2013 Page | 15

Strengths:

Quality Power Supply: HPSEBL has been providing quality and reliable power supply

to its consumers with low voltage fluctuations and power supplied at a stable

frequency.

Lower Losses: HPSEBL has been very proficient in reducing the Distribution losses to

13.43% up to 2011-12 over the last few years. HPSEBL has been and shall always be

committed towards taking the best possible measures to minimise distribution losses

by adopting pro-active approach and adopting best practices prevalent in the

distribution sector in India.

Efficient Customer Service: HPSEBL has been providing efficient services to its

consumers and has also initiated 24 x 7 Call Centres ensuring better services to its

consumers round the clock.

Setting up of Forum for Redressal of Consumer Grievances HPSEBL has constituted

Forum for Redressal of Grievances of consumers of electricity having jurisdiction to

entertain complaints within the area of its distribution licensee, under section 42 of

the Electricity Act 2003 at Shimla.

Weakness:

Ageing Distribution Network: HPSEBL has been supplying electricity for a very long

time and has also been maintaining its network. However, with passage of time the

Distribution Network has started showing signs of ageing and this shall lead to

deterioration in performance of HPSEBL, if adequate and timely steps are not taken.

Uncertainties of Hydro Generation: The own generation of HPSEBL is essentially

Hydro. This involves many uncertainties such as the vintage of hydro stations,

dependency on the quantum of rainfall which leads to uncertainty of generation on a

year on year basis. However, prudent steps taken to ascertain demand for power and

proper scheduling for purchase of power with due consideration to own generation

quantum would help mitigate the uncertainty of hydro power generation.

Ageing Manpower: The Board faces a major challenge in term of ageing manpower

across technical and non-technical category. In order to mitigate this challenge the

board has done proper planning to recruit adequate manpower timely and ensure

proper succession planning in all departments.

Opportunity:

Business growth due to improved lifestyle: Over the last few years, the state has

been experiencing a surge in the population as well as tourism activities. Also due to


Nov, 2013 Page | 16

the improved lifestyle in the area of distribution licencee of a similar kind of trend

shall continue to follow in the near future. As such, HPSEBL foresees an expansion of

Customer base and load growth in its license area.

Increased focus on hydro-generation: Many IPPs are in various stages of

commissioning hydro-generating plants in the state. This increased focus on utilizing

the available hydro-potential by various power sector players is likely to further

improve long term power availability.

Threats

Increase in Coal Prices: It is a well known fact that the recent increase in imported

Coal prices is causing some serious strains to the power utilities. As a result of this,

generators at the central level are seeking increase in tariffs. If such increase in tariff

is allowed in the near future, this increase will have to be borne by the consumers.

HPSEBL feels that this shall cause hardship on its consumers. Further, the capital cost

of newer hydro power plants has gone up substantially resulting in higher power tariff

from new generating units, both under central sector as well as private power

generating companies.

Increasing ACS-ARR Gap: Average Cost of Supply (CoS) of energy at consumer

doorstep has been increasing over the years owing to impact of inflation on various

cost heads, however corresponding increase in Average Rate of Realisation (ARR)

from all category of consumers is not commensurate. As of FY12, the ACS-ARR gap

has reached to 0.61 Rs./unit (ACS=5.28 Rs./unit and ARR=4.67 Rs./unit)

Open Access: With increased focus on providing open access to large consumers, it is

likely that HPSEBL might lose out on these economically attractive consumers. Hence,

it would need to ensure that quality of service to these consumers is sustained and an

economical tariff is levied from them, ensuring customer stickiness.


Nov, 2013 Page | 17

4. SALES

4.1. Load Growth

4.1.1 Table 9 below summarizes the growth in sanctioned load over the past 6 years.

The highest growth of 11.2% has been seen in the Large Industrial category.

Overall growth for the state has been 6.3%.

Table 3: Past years’ load growth

Consumer Category (MW) FY 8 FY 9 FY 10 FY 11 FY 12 FY 13 5 Year

CAGR Actual Actual Actual Actual Actual Actual

Domestic (Including Antodaya) 2083 2169 2260 2381 2497 2637 4.83%

Non Domestic Non Commercial 95 99 107 112 122 134 7.18%

Commercial 436 457 483 505 528 556 4.95%

Temporary 19 21 23 22 24 25 5.82%

Small & Medium Industrial Power Supply

307 329 352 359 361 368 3.66%

Large Industrial Power Supply 838 957 1139 1295 1347 1422 11.16%

LT/HT 603 808 900 917 935 995 10.53%

EHT 235 149 239 377 412 427 12.71%

Govt., Irrigation & Water Supply 194 198 215 226 239 259 5.89%

Public Lighting 3 3 3 6 6 6 11.24%

Agricultural 66 63 67 69 72 79 3.47%

Bulk Supply 89 95 109 107 116 125 7.04%

Total 4132 4392 4758 5080 5312 5610 6.31%

4.1.2 The y-o-y growth in the load for each category has been projected for the control

period based on the past 5 years’ CAGR.

Table 4: Projected load growth during Control Period (FY 2014-15 to FY 2018-19)

Consumer Category (MW) FY 14 FY 15 FY 16 FY 17 FY 18 FY 19

RE Proj. Proj. Proj. Proj. Proj.

Domestic (Including Antodaya) 2764 2898 3038 3184 3338 3499

Non Domestic Non Commercial 144 154 165 177 190 204

Commercial 583 612 642 674 707 743

Temporary 27 28 30 32 34 36

Small & Medium Industrial Power Supply 381 395 410 425 440 456

Large Industrial Power Supply 1581 1758 1955 2174 2418 2690

LT/HT 1100 1216 1344 1486 1642 1815

EHT 481 542 611 689 776 875

Govt., Irrigation & Water Supply 274 290 307 325 344 365

Public Lighting 6 7 8 9 10 11

Agricultural 81 84 87 90 93 96

Bulk Supply 134 143 153 164 176 188

Total 5976 6370 6795 7255 7750 8287


Nov, 2013 Page | 18

4.2. Consumer Growth

4.2.1 HP has witnessed a steady rise in the number of consumers due to natural growth

of population. The rural electrification within the state as on 30.09.2013 stands at

99.9% (as per CEA report)

4.2.2 The Table 7 below summarizes category wise growth in consumers over the past 6

years. As can be seen in the table, overall average consumer growth has been

around 2.5% p.a.

Table 5: Past years’ consumer growth

Consumer Category FY 8 FY 9 FY 10 FY 11 FY 12 FY 13 5 year

CAGR Actual Actual Actual Actual Actual Actual

Domestic (Including Antodaya)

1565173 1591315 1625869 1670476 1719673 1767611 2.5%

Non Domestic Non Commercial

15516 16475 17436 18278 19312 22120 7.3%

Commercial 208568 212102 216688 222936 226911 232723 2.2%

Temporary 2162 2602 3181 3380 3728 4358 15.0%


32288 32147 32736 32591 32715 32782 0.3%

Large Industrial Power Supply

1114 1253 1446 1580 1651 1717 9.0%

LT/HT 1096 1235 1428 1557 1626 1689 9.0%

EHT 18 18 18 23 25 28 9.2%

Govt., Irrigation & Water Supply

3560 3917 4193 4483 4790 5197 7.9%

Public Lighting 592 598 641 702 756 889 8.5%

Agricultural 12561 13732 15204 16811 18190 19946 9.7%

Bulk Supply 161 173 295 325 244 261 10.1%

Total 1841695 1874314 1917689 1971562 2027970 2087604 2.5%

4.2.3 Annual Growth in the number of consumers for the 3rd MYT Control Period is

projected on the basis of the y-o-y growth in the consumers in past 5 years across

different categories. The overall CAGR for these 5 years comes out to be 2.5% as

mentioned above


Nov, 2013 Page | 19

Table 6: Projected consumer growth during Control Period (FY 2014-15 to FY 2018-19)

Consumer Category FY 14 FY 15 FY 16 FY 17 FY 18 FY 19

RE Proj. Proj. Proj. Proj. Proj.

Domestic (Including Antodaya) 1811138 1855737 1901434 1948256 1996232 2045389

Non Domestic Non Commercial 23746 25491 27365 29376 31535 33853

Commercial 237880 243151 248539 254046 259675 265430

Temporary 4794 5273 5800 6381 7019 7720


32882 32982 33082 33183 33284 33385

Large Industrial Power Supply 1807 1898 1993 2092 2197 2307

LT/HT 1773 1862 1955 2053 2156 2263

EHT 34 36 37 39 41 43

Govt., Irrigation & Water Supply 5605 6046 6521 7034 7587 8183

Public Lighting 964 1046 1135 1231 1335 1448

Agricultural 21879 23999 26324 28875 31673 34742

Bulk Supply 287 317 349 384 423 466

Total 2140983 2195939 2252542 2310858 2370959 2432922

4.3. Energy Sales Growth

4.3.1 Table 11 below presents the category-wise energy sales for the past 5 years. The

overall growth in sales has been 7.9% p.a., mainly contributed by increase Large

Supply and Commercial Category.

Table 7: Past years’ growth energy sales growth (MUs)

Consumer Category FY 8 FY 9 FY 10 FY 11 FY 12 FY 13 5 Year CAGR MUs Actual Actual Actual Actual Actual Actual

Domestic (Including Antodaya) 1058 1089 1112 1282 1407 1618 8.87%

Non Domestic Non Commercial 77 81 90 90 99 107 6.67%

Commercial 248 275 306 357 387 409 10.49%

Temporary 23 23 27 25 29 26 2.05%


173 181 176 202 198 206 3.57%

Small Industrial Power Supply 61 59 55 59 58 61 -0.05%

Medium Industrial Power Supply 112 122 120 143 140 145 5.34%

Large Industrial Power Supply 2927 3204 3421 3994 4116 4173 7.35%

LT/HT 1656 1742 1886 2170 2321 2308 6.87%

EHT 1272 1463 1535 1824 1796 1865 7.96%

Govt., Irrigation & Water Supply 335 389 415 410 440 454 6.27%

Public Lighting 13 13 13 13 13 14 1.98%

Agricultural 27 29 37 35 36 47 11.83%

Bulk Supply 147 177 219 236 193 170 2.99%

Total 5029 5461 5814 6642 6918 7224 7.51%

4.3.2 For the 3rd MYT control period (FY 2014-15 to FY 2018-19) the load growth

projections have been made on the basis of category-wise historical CAGRs. The

historical category wise CAGRs are as follows:


Nov, 2013 Page | 20

Table 8: CAGR for past years

CAGR CAGR CAGR

Considered for projections 3 years 5 years

Domestic (Including Antodaya) 8.00% 13.32% 8.87%

Non Domestic Non Commercial 6.00% 5.92% 6.67%

Commercial 7.00% 10.17% 10.49%

Temporary 2.05% -1.45% 2.05%

Small & Medium Industrial Power Supply 3.57% 5.51% 3.57%

Small Industrial Power Supply 2.00% 3.17% -0.05%

Medium Industrial Power Supply 5.34% 6.56% 5.34%

Large Industrial Power Supply 0.00% 6.85% 7.35%

LT/HT 3.50% 6.96% 6.87%

EHT 6.00% 6.70% 7.96%

Govt., Irrigation & Water Supply 5.00% 3.05% 6.27%

Public Lighting 2.00% 3.53% 1.98%

Agricultural 8.00% 8.38% 11.83%

Bulk Supply 2.00% -8.10% 2.99%

4.3.3 The growth in energy sales has been calculated on a monthly basis since the

energy requirement varies a lot during the various seasons of the year in HP. The

MUs sold are identified for each month and for each consumer category. The

increase in the MUs for the particular month is noted for the last 3 years and the

same has been projected in the following years of the control period in order to

get the energy sales for the whole year. Table 12 summarizes the projections of

category wise increase in energy sales over the control period (FY 2014-15 to FY

2018-19), comparing them to the approved sales in the 2nd APR order of FY 2012-

13 for the 2nd Control Period.

Table 9: Projected energy sales’ growth during Control Period (FY 2014-15 to FY 2018-19)

Consumer Category FY 14 FY 14 FY 15 FY 16 FY 17 FY 18 FY 19

MUs Approved RE Proj Proj Proj Proj Proj

Domestic (Including Antodaya) 1756 1781 1923 2077 2243 2423 2616

Non Domestic Non Commercial 115 111 118 125 132 140 149

Commercial 448 428 458 490 524 561 600

Temporary 25 27 27 28 28 29 30


216 209 218 227 237 247 257

Small Industrial Power Supply 62 63 64 65 67 68

Medium Industrial Power Supply

148 155 163 171 180 189

Large Industrial Power Supply 4732 4286 4483 4689 4906 5133 5372

LT/HT 2393 2480 2570 2664 2761 2862

EHT 1893 2003 2119 2242 2372 2510

Govt., Irrigation & Water Supply 539 470 494 519 545 573 602

Public Lighting 14 13 14 14 14 15 15

Agricultural 47 50 54 58 62 67

Bulk Supply 163 158 162 166 170 175 179

Total 8008 7529 7946 8388 8858 9356 9886


Nov, 2013 Page | 21

5. OWN GENERATION

5.1. Generation from own generating stations of HPSEBL

5.1.1 The performance trajectories such as Annual Fixed Cost, Auxiliary consumption

are based on the current condition of the existing plant, the age of the plant,

water availability etc. HPSEBL would like to submit that so far as the performance

of Hydro plants is concerned, they are dependent on the quantum of rainfall

received in the catchment areas as well as the quantum of actual water release

from the connected dams. Hence, they tend to vary over the years.

5.1.2 The following table gives the historical energy generation at HPSEBL’s own

generating plants

Table 10: Past years’ net generation from own plants

Yearly Power Availability (MUs)

Power Availability (MUs) from HPSEBL Stations

Actual Actual Actual RE

Stations FY 10-11 FY 11-12 FY 12-13 FY 13-14

1 Bhaba 642 588 364 537

2 Bassi 192 155 246 240

3 Giri 230 214 196 224

4 Andhra 63 72 65 81

5 Ghanvi 53 61 65 71

6 Baner 37 40 38 40

7 Gaj 31 37 34 39

8 Larji 585 612 573 523

9 Khauli 37 44 41 40

10 Binwa 30 34 29 22

11 Thirot 9 10 13 16

12 Gumma 0 7 4 0

13 Holi 9 5 10 9

14 Bhaba Aug 0 6 10 4

15 Nogli 8 7 6 6

16 Rongtong 1 2 1 2

17 Sal-II 4 4 4 7

18 Chaba 10 9 8 5

19 Rukti 0 1 1 3

20 Chamba 0 0 1 2

21 Killar 0 0 0 1

22 Uhl III - BVPCL 0 0 0 0

23 Ghanvi II 0 0 0 0

Total 1941 1908 1708 1872


Nov, 2013 Page | 22

5.1.3 The MUs generated by each plant have been projected while keeping their actual

generation for the last years in mind. Out of the above mentioned plants, GoHP

has a share of 12% in Ghanvi, Baner, Gaj, Larji, Uhl III and Ghanvi II. Hence,

HPSEBL receives 88% of the overall generation from all of these plants. Rest 12%

is also received by the HPSEBL system through GoHP. The design and energy of

the plants varies a lot during the winters and summers. Hence, monthly

projections of the MUs are done so as to get a better idea of the requirement and

generation.

5.1.4 Based on the above operational parameters, the capacity of the power plant and

the average generation for the past 3 years, the revised estimates for 2013-14 and

projections for the control period of the net generation is given in the following

table:

Table 11: Projected own generation during Control Period (FY 2014-15 to FY 2018-19)

Yearly Power Availability (MUs)

Power Availability (MUs) from HPSEBL Stations

Proj. Proj. Proj. Proj. Proj.

Stations FY 14-15 FY

15-16 FY

16-17 FY

17-18 FY 18-19

1 Bhaba 540 540 540 540 540

2 Bassi 345 345 345 345 345

3 Giri 219 219 219 219 219

4 Andhra 86 86 86 86 86

5 Ghanvi 81 81 81 81 81

6 Baner 53 53 53 53 53

7 Gaj 33 33 33 33 33

8 Larji 501 501 501 501 501

9 Khauli 40 40 40 40 40

10 Binwa 29 29 29 29 29

11 Thirot 18 18 18 18 18

12 Gumma 12 12 12 12 12

13 Holi 12 12 12 12 12

14 Bhaba Aug 18 18 18 18 18

15 Nogli 10 10 10 10 10

16 Rongtong 8 8 8 8 8

17 Sal-II 8 8 8 8 8

18 Chaba 8 8 8 8 8

19 Rukti 6 6 6 6 6

20 Chamba 2 2 2 2 2

21 Killar 1 1 1 1 1

22 Uhl III - BVPCL

0 343 343 343 343

23 Ghanvi II 46 46 46 46 46

Total 2074 2417 2417 2417 2417


Nov, 2013 Page | 23

5.1.5 A new plant Ghanvi-II, with installed capacity of 10 MW, is scheduled to be

commissioned in March 2014.

5.1.6 Based on the price per unit rates of the cost of power for the plants, the total

power purchase cost from Own generation for HPSEBL is as follows:

Table 12: Total Power Purchase Cost from Own Generation

Stations FY 13-14 FY 14-15 FY 15-16 FY 16-17 FY 17-18 FY 18-19

INR Cr RE Proj. Proj. Proj. Proj. Proj.

Bhaba 27.7 34.1 41.4 45.4 51.4 54.0

Bassi 32.4 34.2 36.4 37.3 38.3 39.2

Giri 21.5 23.4 25.6 32.7 55.1 58.8

Andhra 8.1 9.0 10.0 12.4 16.5 17.4

Ghanvi 12.0 18.3 18.3 18.3 18.3 18.3

Baner 8.4 9.1 9.8 10.4 11.1 11.7

Gaj 10.8 11.6 12.4 13.3 14.2 15.1

Larji 130.2 126.4 124.4 122.6 125.2 129.0

Khauli 15.0 17.7 9.0 9.0 9.0 9.0

Binwa 5.1 6.0 7.3 9.8 10.4 11.0

Thirot 6.2 4.0 4.0 4.0 4.0 4.0

Gumma 2.7 2.6 2.6 2.6 2.6 2.6

Holi 2.6 2.6 2.6 2.6 2.6 2.6

Bhaba Aug 3.9 4.0 4.0 4.0 4.0 4.0

Nogli 2.3 2.7 3.1 3.6 4.7 5.1

Rongtong 1.8 1.9 2.2 2.3 2.5 2.7

Sal-II 1.3 1.8 1.8 1.8 1.8 1.8

Chaba 1.9 2.2 2.8 3.1 3.3 3.6

Rukti 0.6 0.7 1.1 1.2 1.3 1.4

Chamba 0.4 0.4 0.4 0.5 0.5 0.5

Killar 0.4 0.3 0.3 0.3 0.3 0.3

Uhl III - BVPCL 0.0 0.0 154.4 154.4 154.4 154.4

Ghanvi II 0.0 16.0 15.1 13.9 13.2 12.6

Total 295.3 328.7 488.9 505.2 544.4 559.0


Nov, 2013 Page | 24

6. POWER PURCHASE PLAN

6.1. Quantum of Power Purchase

The petitioner has to arrange the power requirement of its distribution license area.

In the previous sections, the projected sales and the demand requirement for the

license area has been arrived at and based on the same, the power requirement for

the control period has been discussed in this section.

Apart from the own generation of HPSEBL plants (as discussed in previous sections),

HPSEBL also currently purchases power from various other sources. The main

categories of the generation plants are as follows:

Central Generating Stations (NTPC, NHPC, NJPC and NPC)

HP Quota of BBMB

Independent Power Producers (IPP)

Bilateral Purchase from other states

Purchase of Power from GoHP (Free Power Quota of GoHP under qualified

projects)

Equity power from Nathpa Jhakri Hydro Power Station

Short term contingency purchases from power exchanges

6.2. Power purchase from other generating stations

In Chapter 4, the own generation of HPSEBL was discussed. In addition to self

generation, HPSEBL also procures energy from various other generating stations that

are present in HP or in other surrounded states. Below mentioned are the various

categories of these generating stations:

Table 13: Power Purchase from Other Key Generating Stations

Category Description

GoHP Free

Power

HPSEBL receives the power from GoHP for the plants that are deemed to provide

12% of their power generated to the Government of HP. GoHP sells this power to

HPSEBL at a commission determined rate

NTPC Plants

HPSEBL receives power from the NPTC thermal power plants throughout the year

as per allocated quota. The total allocated capacity from NTPC owned plants ~

1283 units (FY 14) increasing on yoy basis up to 3207(FY 19)

UMPP Orissa

The power procurement from the UMPP Orissa has been tied up and this shall be

of the order of some 700 MUs yearly. However, given the current status of the

bidding, it is not envisaged to get commissioned within this control period (FY 15-

FY19)


Nov, 2013 Page | 25

NPCIL

Currently, HPSEBL is procuring power from NAPP and RAPP (V & VI) stations for

some 200 MUs yearly. It is planned that HPSEBL shall receive around 180 MUs of

energy from RAPP (VII & VIII) from FY 17-18.

NHPC

Currently, HPSEBL receives around 300 MUs of energy from various NHPC plants

present in HP and in Uttarakhand. With the upcoming hydro plants, it is envisaged

that the power procurement from NHPC plants shall increase to 850 MUs by FY

18-19.

THDC HPSEBL receives around 135 MUs from Tehri Hydro Plant and Koteshwar under

SOR

Other CGS and

shared stations

These include Bhakra Nangal and other share stations such as Shanan, Dehar and

Pong. Overall drawal from these stations is somewhere around 1150 MUs yearly.

SJVNL

HPSEBL procures ~ 169 MUs of power from Nathpa Jhakri station under SoR quota

power. In addition, HPSEBL currently also procures 12% power (Allocated to GoHP

against free power) at commission determined price. However, from December

2013 onwards, HPSEBL will surrender its right on 12% free power. However, it will

start procuring 22% (GoHP equity power) from December 2013 onwards till the

end of the control period.

Rampur Power Station is expected to be commissioned by end of FY 14 and is

expected to provide ~ 50 MUs of energy annually till the end of the control period.

SHEPs

There are various small hydro power plants of various capacities. These are

generally divided into less than 5 MW plants, 5 MW to 25 MW plants and greater

than 25 MW plants. Overall these plants provide more than 1000 MUs of energy

yearly to HPSEBL

6.3. Power Purchase Projection Methodology

6.3.1 Power Procurement from GoHP (Free Power Allocation of GoHP)

HPSEBL has procured power from GoHP, (12 % free power share of GoHP) from

CGS stations as well as own stations and IPPs directly connected to HPSEBL

network upto October 2013. However, from December 2013 onwards, significant

quantum of free power (12 % free power share of GoHP) in will be swapped with

the Equity power of GoHP ( 22% Equity power of Govt of HP) from Nathpa Jhakri

HEP for the rest of the base year and control period.

Under this swapping arrangement, the free power share of GoHP shall be

withdrawn from all central generating stations except from Chamera-I, II, III and

Baira Sul. There will be no impact on power flow from generating stations which

are owned by HSEBL or directly connected with HSEBL network.

Table 14: Power Procurement from GoHP (Free Power Allocation of GoHP in MUs)

Stations Plant

capacity Share 12-13 13-14 14-15 15-16 16-17 17-18 18-19

MUs MW % Actual RE Proj. Proj. Proj. Proj. Proj.

Baira Siul 180 12% 41.1 30.5 0.0 0.0 0.0 0.0 0.0


Nov, 2013 Page | 26

Chamera-I 540 12% 114.4 80.8 0.0 0.0 0.0 0.0 0.0

Chamera-II 300 12% 144.5 88.6 0.0 0.0 0.0 0.0 0.0

Chamera-III 231 12% 25.1 20.5 0.0 0.0 0.0 0.0 0.0

Shanan Share 0.5 Fixed 2.6 2.6 2.6 2.6 2.6 2.6 2.6

Ranjeet Sagar Dam Share 600 5% 62.5 75.8 69.4 69.4 69.4 69.4 69.4

Malana 86 15% 49.4 56.2 73.3 73.3 73.3 73.3 73.3

Baspa (Primary & Sec.) 300 12% 147.2 160.0 153.7 153.7 153.7 153.7 153.7

Nathpa Jhakri HEP 1500 12% 386.5 688.4 0.0 0.0 0.0 0.0 0.0

Ghanvi 22.5 12% 8.8 9.7 11.1 11.1 11.1 11.1 11.1

Baner 12 12% 5.2 5.5 7.2 7.2 7.2 7.2 7.2

Gaj 10.5 12% 4.7 5.3 4.6 4.6 4.6 4.6 4.6

Larji 126 12% 78.1 71.3 68.3 68.3 68.3 68.3 68.3

Khauli 12 12% 5.6 5.5 5.4 5.4 5.4 5.4 5.4

Budhil 70 12% 1.8 3.5 0.0 0.0 0.0 0.0 0.0

Allian Duhangan 192 12% 15.9 9.3 0.0 0.0 0.0 0.0 0.0

Kol Dam 800 12% 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Parbati-II 800 12% 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Parbati-III 520 12% 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Rampur project 412 12% 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Karcham Wangtoo 1000 12% 77.4 80.2 0.0 0.0 0.0 0.0 0.0

Sawra Kuddu 111 12% 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Uhl-III 100 13% 0.0 0.0 0.0 46.8 46.8 46.8 46.8

Ghanvi II 10 12% 0.0 0.0 6.2 6.2 6.2 6.2 6.2

Malana II 100 12% 3.1 3.9 0.0 0.0 0.0 0.0 0.0

Kashang I, II, III 195 12% 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Kashang IV 48 12% 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Sainj 100 12% 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Tidong 60 12% 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Song tong Karcham 450 12% 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Chirgaon Majgaon 42 12% 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Renuka Dam 40 12% 0.0 0.0 0.0 0.0 0.0 0.0 0.0

SHEP Allocated Varies Varies 33.6 41.5 39.7 43.2 46.6 50.1 53.5

Total 1207.5 1439.2 441.5 491.8 495.2 498.7 502.1

The total power procurement cost for the above mentioned plants is as follows:

Table 15: Total Power Purchase Cost from GoHP



Baira Siul 8.9 0.0 0.0 0.0 0.0 0.0

Chamera-I 23.6 0.0 0.0 0.0 0.0 0.0

Chamera-II 25.9 0.0 0.0 0.0 0.0 0.0

Chamera-III 6.0 0.0 0.0 0.0 0.0 0.0

Shanan Share 0.8 0.8 0.8 0.8 0.8 0.8

Ranjeet Sagar Dam Share 22.1 20.3 20.3 20.3 20.3 20.3

Malana 16.4 21.4 21.4 21.4 21.4 21.4

Baspa (Primary & Sec.) 46.7 44.9 44.9 44.9 44.9 44.9

Nathpa Jhakri HEP 201.0 0.0 0.0 0.0 0.0 0.0

Ghanvi 2.8 3.2 3.2 3.2 3.2 3.2

Baner 1.6 2.1 2.1 2.1 2.1 2.1


Nov, 2013 Page | 27

Gaj 1.6 1.3 1.3 1.3 1.3 1.3

Larji 20.8 19.9 19.9 19.9 19.9 19.9

Khauli 1.6 1.6 1.6 1.6 1.6 1.6

Budhil 1.0 0.0 0.0 0.0 0.0 0.0

Allian Duhangan 2.7 0.0 0.0 0.0 0.0 0.0

Kol Dam 0.0 0.0 0.0 0.0 0.0 0.0

Parbati-II 0.0 0.0 0.0 0.0 0.0 0.0

Parbati-III 0.0 0.0 0.0 0.0 0.0 0.0

Rampur project 0.0 0.0 0.0 0.0 0.0 0.0

Karcham Wangtoo 23.4 0.0 0.0 0.0 0.0 0.0

Sawra Kuddu 0.0 0.0 0.0 0.0 0.0 0.0

Uhl-III 0.0 0.0 13.7 13.7 13.7 13.7

Ghanvi II 0.0 1.8 1.8 1.8 1.8 1.8

Malana II 1.1 0.0 0.0 0.0 0.0 0.0

Kashang I, II, III 0.0 0.0 0.0 0.0 0.0 0.0

Kashang IV 0.0 0.0 0.0 0.0 0.0 0.0

Sainj 0.0 0.0 0.0 0.0 0.0 0.0

Tidong 0.0 0.0 0.0 0.0 0.0 0.0

Song tong Karcham 0.0 0.0 0.0 0.0 0.0 0.0

Chirgaon Majgaon 0.0 0.0 0.0 0.0 0.0 0.0

Renuka Dam 0.0 0.0 0.0 0.0 0.0 0.0

SHEP Allocated 12.1 11.6 12.6 13.6 14.6 15.6

Total 420.2 128.9 143.6 144.6 145.6 146.6

6.3.2 NTPC Plants:

The quantum of power purchase from NTPC plants for 2013-14 is based on actual

monthly actual monthly quantum upto October 2013 and the balance six months

(Nov 13- Dec 13) base year projection as well as the control period FY 2014-18 to

FY2018-19 is based on the average PLF of the individual plants and the allocated

share of HPSEBL from these plants.

Table 16: Power procurement from NTPC owned plants

Stations Plant

capacity Share 12-13

13-14

14-15 15-16 16-17 17-18 18-19


Anta (G) 419.33 3.58% 73.9 74.8 87.7 87.7 87.7 87.7 87.7

Anta (L) 419.33 3.58% 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Anta (LNG) 419.33 3.58% 3.2 0.1 0.0 0.0 0.0 0.0 0.0

Auriya (G) 663.36 3.32% 65.5 74.5 122.4 122.4 122.4 122.4 122.4

Auriya (L) 663.36 3.32% 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Auriya (LNG) 663.36 3.32% 4.7 0.2 0.0 0.0 0.0 0.0 0.0

Dadri (G) 829.78 3.01% 106.9 113.3 152.0 152.0 152.0 152.0 152.0

Dadri (L) 829.78 3.01% 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Dadri (LNG) 829.78 3.01% 4.7 0.1 0.0 0.0 0.0 0.0 0.0

Unchahar-I 420 1.67% 56.3 43.4 51.9 51.9 51.9 51.9 51.9

Unchahar-II 420 2.86% 107.1 80.6 87.7 87.7 87.7 87.7 87.7

Unchahar-III 210 3.81% 68.3 49.2 58.5 58.5 58.5 58.5 58.5

Rihand-1 STPS 1000 3.50% 270.9 240.6 263.7 263.7 263.7 263.7 263.7


Nov, 2013 Page | 28

Rihand-2 STPS 1000 3.30% 315.2 220.1 260.8 260.8 260.8 260.8 260.8

Singrauli STPS 2000 0.00% 124.1 97.6 0.0 0.0 0.0 0.0 0.0

Kahalgaon – II 1500 1.53% 134.3 128.2 130.8 130.8 130.8 130.8 130.8

Rihand-3 Units-1,2 1000 3.37% 36.9 155.6 255.7 255.7 255.7 255.7 255.7

Dadri-II TPS 980 0.00% 53.9 42.2 0.0 0.0 0.0 0.0 0.0

Jhajjar TPS 1000 0.00% 32.9 29.5 0.0 0.0 0.0 0.0 0.0

Singrauli Solar 15 100.00% 0.0 0.0 99.5 132.6 132.6 132.6 132.6

Kol dam HEP 800 3.36% 0.0 0.0 50.9 100.3 100.3 100.3 100.3

North Karanpura 1980 1.53% 0.0 0.0 0.0 0.0 0.0 0.0 223.8

Meja 1320 1.44% 0.0 0.0 0.0 0.0 140.4 140.4 140.4

Lata Tapowan HEP 171 1.53% 0.0 0.0 0.0 0.0 0.0 10.2 10.2

Rupsia Bagar HEP 261 1.53% 0.0 0.0 0.0 0.0 14.7 14.7 14.7

Singrauli III 500 3.50% 0.0 0.0 0.0 0.0 0.0 0.0 129.3

Tanda II 1320 3.50% 0.0 0.0 0.0 0.0 0.0 0.0 341.3

Tapovan Vishnugarh HEP 520 1.53% 0.0 0.0 0.0 29.4 29.4 29.4 29.4

Gider Baha 2640 1.50% 0.0 0.0 0.0 0.0 0.0 307.9 307.9

Unchahar IV 500 2.00% 0.0 0.0 0.0 0.0 73.9 73.9 73.9

Bilhaur 660 3.00% 0.0 0.0 0.0 0.0 0.0 0.0 146.3

Total 1459 1350 1622 1734 1963 2281 3121


Table 17: Total Power Purchase Cost from NTPC Stations



Anta (G) 33.9 42.9 46.3 50.0 54.0 58.4

Anta (L) 0.0 0.0 0.0 0.0 0.0 0.0

Anta (LNG) 0.1 0.0 0.0 0.0 0.0 0.0

Auriya (G) 35.4 62.8 67.9 73.3 79.2 85.5

Auriya (L) 0.0 0.0 0.0 0.0 0.0 0.0

Auriya (LNG) 0.2 0.0 0.0 0.0 0.0 0.0

Dadri (G) 51.1 74.1 80.0 86.4 93.3 100.8

Dadri (L) 0.0 0.0 0.0 0.0 0.0 0.0

Dadri (LNG) 0.1 0.0 0.0 0.0 0.0 0.0

Unchahar-I 15.8 20.4 22.0 23.7 25.6 27.7

Unchahar-II 31.1 36.5 39.5 42.6 46.0 49.7

Unchahar-III 20.5 26.3 28.4 30.7 33.2 35.8

Rihand-1 STPS 50.7 60.1 64.9 70.1 75.7 81.7

Rihand-2 STPS 48.0 61.4 66.3 71.6 77.3 83.5

Singrauli STPS 15.3 0.0 0.0 0.0 0.0 0.0

Kahalgaon - II 45.8 50.5 54.5 58.9 63.6 68.7

Rihand-3 Units-1,2 58.0 102.9 111.1 120.0 129.6 139.9

Dadri-II TPS 20.4 0.0 0.0 0.0 0.0 0.0

Jhajjar TPS 16.6 0.0 0.0 0.0 0.0 0.0

Singrauli Solar 0.0 44.8 62.6 65.8 69.1 72.5

Kol dam HEP 0.0 22.9 45.1 45.1 45.1 45.1

North Karanpura 0.0 0.0 0.0 0.0 0.0 106.6

Meja 0.0 0.0 0.0 57.3 61.9 66.9

Lata Tapowan HEP 0.0 0.0 0.0 0.0 4.6 4.6

Rupsia Bagar HEP 0.0 0.0 0.0 6.6 6.6 6.6


Nov, 2013 Page | 29

Singrauli III 0.0 0.0 0.0 0.0 0.0 61.6

Tanda II 0.0 0.0 0.0 0.0 0.0 162.5

Tapovan Vishnugarh HEP 0.0 0.0 13.2 13.2 13.2 13.2

Gider Baha 0.0 0.0 0.0 0.0 135.8 146.6

Unchahar IV 0.0 0.0 0.0 30.2 32.6 35.2

Bilhaur 0.0 0.0 0.0 0.0 0.0 69.6

Total 442.8 605.5 701.8 845.5 1046.3 1522.7

6.3.3 NPCIL Plants:

HPSEBL procures power from NPCIL stations NAPP and RAPP Units 5 & 6 based on

allocated share of HPSEBL from these plants. The monthly power purchase

quantum from these plants for FY 2013-14 is based on actual purchase from these

plants upto October 2013 and based on the monthly average quantum procured

from these plants during the past 3 years for the remaining months. The same

methodology of monthly average of past 3 years is used for projections of power

purchase quantum for the control period from FY 2014-18 to FY 2018-19. Units VII

and VIII are under construction and expected to get commissioned by end of

March 2017.

Table 18: Power procurement from NPCIL plants

Stations Plant

capacity Share 12-13 13-14 14-15 15-16 16-17 17-18 18-19


NAPP 440 3.18% 91.5 89.9 74.0 74.0 74.0 74.0 74.0

RAPP (V & VI) 440 3.41% 151.5 155.2 135.1 135.1 135.1 135.1 135.1

RAPP (VII & VIII) 1400 1.90% 0.0 0.0 0.0 0.0 0.0 190.1 190.1

Total 243.0 245.1 209.1 209.1 209.1 399.2 399.2


Table 19: Total Power Purchase Cost from NPCIL Stations



NAPP 24.5 22.2 22.2 22.2 22.2 22.2

RAPP (V & VI) 58.4 56.0 56.0 56.0 56.0 56.0

RAPP (VII & VIII) 0.0 0.0 0.0 0.0 78.7 78.7

Total 82.9 78.1 78.1 78.1 156.8 156.8

6.3.4 NHPC Plants:

The quantum of power purchase from NHPC plants for FY 2013-14 is calculated

based on the monthly actual power purchase quantum upto October 2013 and for


Nov, 2013 Page | 30

the remaining months based on the average monthly power purchase quantum of

last 3 years i.e. 2010-11, 2011-12, 2012-13. The power purchase quantum for the

control period is also based on the average monthly power purchase quantum for

the past 3 years.

Table 20: Power Procurement from NHPC plants

Stations Plant

capacity Share 12-13 13-14 14-15 15-16 16-17 17-18 18-19


Salal 690 0.99% 32.4 30.2 30.2 30.2 30.2 30.2 30.2

Tanakpur 94.2 3.84% 14.4 14.2 14.8 14.8 14.8 14.8 14.8

Chamera I 540 2.90% 70.5 63.3 47.7 47.7 47.7 47.7 47.7

Chamera II 300 3.67% 64.1 61.1 54.4 54.4 54.4 54.4 54.4

Chamera III 231 3.36% 24.6 37.2 33.2 33.2 33.2 33.2 33.2

Uri 480 2.71% 80.3 67.6 69.3 69.3 69.3 69.3 69.3

Dhauliganga 280 3.57% 46.6 13.6 40.5 40.5 40.5 40.5 40.5

Dulhasti 380 UA 15.4 10.0 0.0 0.0 0.0 0.0 0.0

Sewa 120 UA 5.0 2.3 0.0 0.0 0.0 0.0 0.0

Parbati II 800 3.36% 0.0 0.0 0.0 0.0 86.3 86.3 86.3

Parbati III 520 3.36% 0.0 0.0 56.3 65.6 65.6 65.6 65.6

Kotli Behal 1045 2.47% 0.0 0.0 0.0 113.0 113.0 113.0 113.0

Total 353.3 299.4 346.3 468.7 555.0 555.0 555.0


Table 21: Total Power Purchase Cost from NHPC Stations



Salal 4.3 4.4 4.5 4.7 4.8 5.0

Tanakpur 3.5 3.8 3.9 4.0 4.1 4.3

Chamera I 10.6 8.2 8.5 8.7 9.0 9.2

Chamera II 19.1 17.6 18.1 18.6 19.2 19.8

Chamera III 18.4 16.9 17.4 17.9 18.4 19.0

Uri 13.0 13.7 14.1 14.5 15.0 15.4

Dhauliganga 4.4 13.6 14.0 14.4 14.9 15.3

Dulhasti 6.8 0.0 0.0 0.0 0.0 0.0

Sewa 1.1 0.0 0.0 0.0 0.0 0.0

Parbati II 0.0 0.0 0.0 38.8 38.8 38.8

Parbati III 0.0 25.3 29.5 29.5 29.5 29.5

Kotli Behal 0.0 0.0 50.9 50.9 50.9 50.9

Total 81.2 103.5 160.9 202.1 204.6 207.2

6.3.5 THDC Plants:

The availability from Tehri Hydro for FY 2013-14 is based on actual purchase upto

October 2013 and the monthly average purchase of past three years for the


Nov, 2013 Page | 31

remaining period. The projections for FY 2014-15 to FY 2018-19 are also based on

the monthly purchase quantum for FY 2013-14.

Table 22: Power procurement from THDC plants

Stations Plant

capacity Share 12-13 13-14 14-15 15-16 16-17 17-18 18-19


Tehri 1000 2.80% 104.5 121.0 101.0 101.0 101.0 101.0 101.0

Koteshwar 400 2.51% 35.7 35.5 31.0 31.0 31.0 31.0 31.0

Total 140.2 156.5 132.0 132.0 132.0 132.0 132.0


Table 23: Total Power Purchase Cost from THDC Stations



Tehri 62.0 54.4 57.1 60.0 63.0 66.1

Koteshwar 16.3 14.9 15.6 16.4 17.2 18.1

Total 78.3 69.3 72.7 76.4 80.2 84.2

6.3.6 SJVN Stations:

The power availability from Nathpa Jhakri for FY 2013-14 is based on the actual

quantum upto October 2013 and for the remaining months based on the average

quantum for past three years. The projections for the control period from Nathpa

Jhakri are also based on the same mechanism. Projections for the upcoming

Rampur HEP under SJVNL are based on the allocated share of HPSEBL from the

station and the monthly design energy. HPSEBL shall also procure 22% equity

power from Nathpa Jhakri from December 2013 onwards for FY 2013-14 and

further for the entire control period. The quantum is calculated based on the

allocated share of HPSEBL for the equity power and the design energy.

Table 24: Power procurement from SJVN Stations

Stations Plant

capacity Share 12-13 13-14 14-15 15-16 16-17 17-18 18-19


Nathpa Jhakri SOR 1500 2.47% 193 200 169 169 169 169 169

Nathpa Jhakri Equity 1500 22.00% 0 233 1505 1505 1505 1505 1505

Rampur 412 2.81% 0 0 58 58 58 58 58

Luhri 775 2.47% 0 0 0 0 0 0 84

Total 193 432 1732 1732 1732 1732 1816



Nov, 2013 Page | 32

Table 25: Total Power Purchase Cost from SJVN



Nathpa Jhakri SOR 60.6 52.3 53.3 54.4 55.5 56.6

Nathpa Jhakri Equity 70.6 465.8 475.1 484.6 494.3 504.2

Rampur 0.0 26.0 26.0 26.0 26.0 26.0

Luhri 0.0 0.0 0.0 0.0 0.0 37.7

Total 131.2 544.1 554.4 565.0 575.8 624.5

6.3.7 Other CGS and shared stations:

The power purchase quantum from BBMB Old is based on fixed share of 1.2 Lakh

units of HPSEBL from this plant. The power purchase quantum for BBMB New,

Dehar and Pong is based on actual quantum purchased from these stations upto

October 2013 for FY 2013-14. The projections for the control period i.e. FY 2014-

15 to FY 2018-19 are based on the allocation of HPSEBL from these plants and the

projected quantum for FY 2013-14. Shanan and Shanan Extension has fixed share

to HPSEBL and based on this, projections are made for these stations. Energy

availability from Yamuna (UJVNL) and Khara has been considered at actual upto

October 2013 for FY 2013-14 and for remaining months based on average

generation level of last three years. Projections for the control period from these

plants are also based on the same methodology.

Table 26: Power procurement from shared stations

Stations Plant

capacity Share 12-13 13-14 14-15 15-16 16-17 17-18 18-19


BBMB Old 0 Fixed 1.2LU/day 43.8 43.9 43.9 43.9 43.9 43.9 43.9

BBMB New 1480 7.19% 318.4 411.3 326.3 326.3 326.3 326.3 326.3

Dehar 990 7.19% 180.9 199.4 187.1 187.1 187.1 187.1 187.1

Pong 396 7.19% 53.5 54.4 46.4 46.4 46.4 46.4 46.4

Shanan 60 Fixed 1MW 5.3 5.2 5.2 5.2 5.2 5.2 5.2

Shanan Ext 50 Fixed 45 MU 45.0 45.0 45.0 45.0 45.0 45.0 45.0

Yamuna 474.7 24.68% 438.1 450.2 387.8 387.8 387.8 387.8 387.8

Khara 72 20.00% 71.9 53.0 56.6 56.6 56.6 56.6 56.6

Total 1156.9 1262.4 1098.2 1098.2 1098.2 1098.2 1098.2


Table 27: Total Power Purchase Cost from Other CGS and shared stations



BBMB Old 3.8 4.1 4.6 5.0 5.5 6.0

BBMB New 22.1 18.4 19.3 20.3 21.3 22.4


Nov, 2013 Page | 33

Dehar 15.0 14.8 15.5 16.3 17.1 18.0

Pong 1.8 1.6 1.7 1.8 1.8 1.9

Shanan 0.2 0.2 0.2 0.3 0.3 0.3

Shanan Ext 1.0 1.0 1.1 1.1 1.2 1.2

Yamuna 28.8 28.6 30.6 32.8 35.1 37.5

Khara 3.8 4.2 4.3 4.4 4.6 4.7

Total 76.5 73.0 77.3 81.9 86.8 92.0

6.3.8 RPO Obligations

HPSEBL has abundant procurement of non-solar renewable power to meet its

RPO obligations. In case of solar RPO obligations, it is expected that HPSEBL shall

procure more solar power from other stations apart from Singrauli to meet its

RPO obligations. The additional requirement is estimated as follows:

Table 28: Additional Solar Power Requirement

FY 13-

14 FY 14-

15 FY 15-

16 FY 16-

17 FY 17-

18 FY 18-

19

Solar RPO Obligation 0.25% 0.25% 0.25% 0.25% 0.50% 0.75%

Requirement in MUs 21.71 22.83 24.03 25.31 53.31 84.26

Additional required as per July 2013 order of HPERC 0.00 0.00 0.74 18.40 0.00 0.00

Availability from Singrauli 0.00 19.08 25.44 25.44 25.44 25.44

Additional Solar Power Required 21.71 3.75 0.00 18.26 27.87 58.81

6.3.9 Small Hydro (SHEPs):

The power availability from SHEPs for FY 2013-14 is based on three month actual

from these plants. For remaining months, the monthly average availability from

SHEPs for 2012-13 is used for projections. For the control period, the projections

for the quantum are based on estimated escalation of 1% for SHEPs below and

upto 5MW, 5% for plants above 5 MW and upto 25 MW and 2% for plants under

REC tariff.

The power availability from Baspa II (Primary energy) for FY 2013-14 is at actual

upto October 2013 and for the remaining months; it is calculated as the average

of the remaining months for FY 2012-13. For Baspa II secondary energy, similar

methodology is used. For projections for the control period for FY 2014-15 to FY

2018-19, the average generation of past three years is used for projections.

Table 29: Power procurement from other stations

Stations Share 12-13 13-14 14-15 15-16 16-17 17-18 18-19

MUs % Actual RE Proj. Proj. Proj. Proj. Proj.

Small HEP/ Private Micro 906 1052 1152 1252 1352 1452 1552


Nov, 2013 Page | 34

Small HEP/ Private Micro – REC 117 141 107 117 126 135 145

Baspa - II 88.00% 1079 1207 1127 1127 1127 1127 1127

Additional Solar Power 21.7 3.7 0.0 18.3 27.9 58.8

Total 2102.4 2422.1 2390.9 2496.4 2624.0 2742.9 2883.2


Table 30: Total power purchase cost from other stations



Small HEP/ Private Micro 342.0 374.5 407.0 439.5 472.0 504.5

Small HEP/ Private Micro – REC 30.7 24.5 27.9 31.7 35.7 40.1

Baspa – II 364.4 340.4 340.4 340.4 340.4 340.4

Additional Solar Power 12 2 0 10 15 32

Total 749.0 741.5 775.4 821.7 863.5 917.4

6.3.10 Unallocated power from other sources

HPSEBL also envisages procuring 350 MUs annually from various CGS, especially in

the winter months to cater to its high demand during this period.

The following table gives the projection of power procurement from these

sources:

Table 31: Power Purchase (MUs) from other sources

Stations 12-13 13-14 14-15 15-16 16-17 17-18 18-19

MUs Actual RE Proj. Proj. Proj. Proj. Proj.

Unallocated share from CGS 0.0 0.0 350.0 350.0 350.0 350.0 350.0

UI 212 163 0 0 0 0 0

Banking availed at gen bus 1170 1214 1200 1200 1200 1200 1200

Contingency Power purchase at periphery

61.9 85.2 24.1 79.6 155.8 136.2 35.4

Total 1444 1462 1574 1630 1706 1686 1585 Note: Unallocated Allocation for winter month to HPSEBL is already included in actual power purchase of FY 2012-13 and RE

of FY 2013-14

The following table gives the projection of total power procurement cost from

these sources:

Table 32: Total Power Purchase Cost from other sources

Stations FY 13-

14 FY 14-15 FY 15-16 FY 16-17 FY 17-18 FY 18-19


Unallocated share from CGS 0.0 124.4 131.8 139.7 148.2 157.3

UI 19.8 0.0 0.0 0.0 0.0 0.0

Banking availed at gen bus 0.0 0.0 0.0 0.0 0.0 0.0

Contingency Power purchase at periphery 29.6 8.8 30.5 62.7 57.5 15.7

Total 49.4 133.2 162.3 202.3 205.7 173.0


Nov, 2013 Page | 35

6.3.11 Summary

Table 33: Overall Power Purchase (MUs)

Stations/ Sources FY 12-13 FY 13-14 FY 14-15 FY 15-16 FY 16-17 FY 17-18 FY 18-19

MUs Actual RE Proj. Proj. Proj. Proj. Proj.

Own generation 1707.7 1871.8 2073.9 2417.0 2417.0 2417.0 2417.0

Free power 1207.5 1439.2 441.5 491.8 495.2 498.7 502.1

NTPC 1458.7 1349.9 1621.8 1733.6 1962.6 2280.7 3121.4

NPCIL 243.0 245.1 209.1 209.1 209.1 399.2 399.2

NHPC 353.3 299.4 346.3 468.7 555.0 555.0 555.0

THDC 140.2 156.5 132.0 132.0 132.0 132.0 132.0

SJVN Stations 192.9 432.3 1731.8 1731.8 1731.8 1731.8 1815.6

Other sources 1444 1462 1574 1630 1706 1686 1585

Shared Stations 1156.9 1262.4 1098.2 1098.2 1098.2 1098.2 1098.2

Other Stations 2102.4 2422.1 2390.9 2496.4 2624.0 2742.9 2883.2

Total 10006.5 10941.0 11619.6 12408.2 12930.7 13541.6 14509.0

Table 34: Total Power Purchase Cost



Own generation 295.3 328.7 488.9 505.2 544.4 559.0

Free power 420.2 128.9 143.6 144.6 145.6 146.6

NTPC 442.8 605.5 701.8 845.5 1046.3 1522.7

NPCIL 82.9 78.1 78.1 78.1 156.8 156.8

NHPC 81.2 103.5 160.9 202.1 204.6 207.2

THDC 78.3 69.3 72.7 76.4 80.2 84.2

SJVN Stations 131.2 544.1 554.4 565.0 575.8 624.5

Other sources 49.4 133.2 162.3 202.3 205.7 173.0

Shared Stations 76.5 73.0 77.3 81.9 86.8 92.0

Other Stations 749.0 741.5 775.4 821.7 863.5 917.4

Total 2406.9 2805.7 3215.5 3522.9 3909.8 4483.4

Table 35: Average Cost of Power Procurement (INR/ Unit)

INR/ Unit 12-13 13-14 14-15 15-16 16-17 17-18 18-19

Average Cost of Power Procurement 1.80 2.20 2.41 2.59 2.72 2.89 3.09


Nov, 2013 Page | 36

7. T & D LOSS TRAJECTORIES & ENERGY BALANCE

7.1. Transmission and Distribution Losses

7.1.1 For the 2nd Control Period, the Commission had considered the T&D loss

reduction trajectory of 0.11%, 0.15% and 0.40% in FY12, FY13 and FY14,

respectively, to reach a level of 12.00% by the end of the Control Period.

7.1.2 Further, HPSEBL had proposed a revised trajectory with loss levels of 13.43%,

13.03% & 12.73% for FY12, FY13 & FY14 respectively, in the 2nd APR petition for

the 2nd MYT control period.

7.1.3 HPSEBL has submitted that the actual loss level achieved in FY12 was 13.43% and

in FY13 is 13.62%. The same is expected to be 13.3% for FY14.

7.1.4 This increase in T&D loss has been a result of three factors – First, industrial

consumers that are supplied power at higher voltages result in lower losses for

this category. However, recently their growth has tapered down when compared

to other consumer categories with higher loss numbers, resulting in an overall

increase in T&D losses. Second, there has been wide-spread rural electrification

under the RGGVY schemes leading to an increase in the HT:LT ratio, which has

resulted in overall increase in T&D losses. As the losses for RGGVY consumers are

high, it has resulted in an overall increase in T&D losses. Third, there is an

increasing trend of many bulk consumers opting for Open Access and this trend is

expected to grow in coming years. These bulk consumers are connected at HT

level where the T&D losses are low. Due to the moving out of bulk consumers

connected at high voltage, the overall T&D loss have increased.

7.1.5 The current loss level is far lesser than the loss levels prevalent in HP’s

neighbouring states. Further, the T&D loss level of the HPSEBL should be set at a

realistic level keeping in view the following factors:

a. Inherent disadvantage of the State due to scattered population, difficult

terrain, low load density and long sub-transmission & distribution lines.

b. Other utilities have advantage of underground cabling, which is not realistic in

the case in HP.

7.1.6 The proposed T&D Loss trajectory for the 3rd MYT Control Period is as follows:


Nov, 2013 Page | 37

Table 36: Proposed T&D Loss Trajectory

FY 14 FY 15 FY 16 FY 17 FY 18 FY 19

T&D Losses 13.30 % 13.00% 12.75% 12.50% 12.25% 12.00%

Loss Reduction 0.30% 0.25% 0.25% 0.25% 0.25%

7.1.7 HPSEBL requests the Commission to revisit and revise the T&D loss reduction

trajectory in a realistic manner based on the actual T&D loss for the past years

and considering the above mentioned factors so that HPSEBL can meet the T&D

loss reduction trajectory.

7.1.8 Based on the proposed loss levels and projected energy requirement and

availability within the state, the Energy Balance is presented in the following

table:

Table 37: Energy Balance

MUs FY 13 FY 14 FY 15 FY 16 FY 17 FY 18 FY 19

Power Procurement

Own sources 10007 10941 11620 12408 12931 13542 14509

Others - Interstate, Banking, etc 7078 7630 8116 8350 8665 9173 10098

Transmission losses 215 249 269 276 286 304 334

Total availability at HPSEBL periphery

9791 10692 11350 12132 12644 13238 14175

Sales - within the state 7224 7529 7946 8388 8858 9356 9886

T&D losses 13.62% 13.29% 13.00% 12.75% 12.5% 12.25% 12.00%

Power required at HPSEBL periphery for intra state sales

8363 8683 9133 9614 10123 10663 11234

Banking sale / return at discom periphery

877 1312 1542 1200 1200 1200 1200

Interstate sales at periphery 552 698 675 1318 1321 1376 1740

Total power required at HPSEBL periphery

9791 10692 11350 12132 12644 13238 14175


Nov, 2013 Page | 38

8. TRANSMISSION CHARGES

There are some key components of the total transmission costs paid by HPSEBL. These

components along with the methodology for the calculation of their charges are given

below:

PGCIL Charges: These are paid to PGCIL for the transmission of power procured by HPSEBL

from inter-state sources. These are charged per MW per month for the total power being

transferred through the PGCIL transmission lines. For FY 14, the PGCIL charges considered

are INR 1,76,560 per MW per month. An annual escalation of 10% in the same has been

assumed for the control period. As HPSEBL also pays PGCIL for the power transmitted by the

later for GoHP, their subsequent recoveries from GoHP have been netted out of the total

charges paid to PGCIL.

HPPTCL Charges: Calculated based on the expected increase in the ARR of HPPTCL for the

control period. The same are subject to the final approval of ARR of HPPTCL by the Hon’ble

Commission.

ULDC Charges: ULDC charge are paid to PGCIL for the Unified Load Dispatch and

Communication scheme in the form of state and central sector equipment cost and central

sector O&M cost. HPSEBL pays the ULDC I scheme equipment cost share of 25 Crores over a

tenure of 15 years which is to be completed by FY 2017-18. ULDC II HPSEBL share cost is 5

Crore which HPSEBL will start paying after the commissioning of scheme in FY 2014-15.

O&M cost are raised monthly by NRLDC to the board in form System operation charges and

Market operation charges. O&M cost is calculated considering 5% year on year escalation

on annual O&M cost paid by HPSEBL for FY 12-13.

STOA: These are paid to PGCIL and state transmission utilities in the form of withdrawal

charges, STU charges and RLDC and SLDC fees for power procured from Banking and Day

Ahead Market sources. HPSEBL also pay these charges in form of Injection charges, STU

charges and RLDC and SLDC fees for interstate and banking power sale. The injection and

drawl charges (Paisa/ Unit) are calculated considering 8 % year on year escalation on Fy

2013-14 Q4 notified Zonal PoC slab rates. STU charges are calculated considering 8% year on

year escalation on current STU charge of 2 Paisa/ unit. The Fees and charges including

application fees, RLDC and SLDC fees are calculated considering 3% year on year escalation

on current fees.

Table 38: Summary of Transmission Charges (INR Cr)

Description 13-14 14-15 15-16 16-17 17-18 18-19

(Est) (Proj.) (Proj.) (Proj.) (Proj.) (Proj.)

PGCIL Charges 217 304 346 382 455 639

HPPTCL Charges Payable 12 12 17 20 22 24


Nov, 2013 Page | 39

ULDC Charges 9 6 6 6 3 1

STOA Charges 26 49 53 67 77 6

O&M Charges 2 2 2 2 2 2

Total 267 373 425 477 558 670


Nov, 2013 Page | 40

9. CAPITAL INVESTMENT PLAN

9.1. Capital Investment plan for Distribution schemes

9.1.1 As has been discussed, HPSEBL is engaged in the activities of (i) generation from

power houses under operation (ii) distribution of electricity in its area of supply

i.e. HP (iii) trading of electricity (iv) operation & maintenance of all existing

generating plants, evacuation lines & EHV, HV, LV Distribution Network and (v)

completion of existing generating stations & execution of Hydro Projects as

allocated by GoHP along with associated EHV network

9.1.2 Based upon the above mandate the CAPEX Plan proposals (scheme wise) for FY

13-14 to FY 18-19 under 3nd MYT Control Period FY 2014-19 have been formulated

by HPSEB Ltd. under following major heads in order to effect better planning,

budgeting and monitoring at macro & micro levels:

1. EHV DISTRIBUTION SCHEMES (66KV AND ABOVE) 2. ALDC, SYSTEM OPERATION, COMMUNICATION SYSTEMS ETC. 3. HV, LV DISTRIBUTION SCHEMES (33KV AND BELOW) 4. I.T. SCHEMES

9.1.3 EHV Distribution Schemes (66 kV and above)

9.1.3.1 Himachal Pradesh being predominantly Hydro State has surplus power during

summer/monsoon months but faces acute shortage of power during winter

months and HPSEBL have to depend upon power flows from outside the State.

Taking this available power from periphery to load centers for further distribution

to consumers and industrial areas like Baddi, Barotiwala, Kala Amb, Paonta etc.,

HPSEBL has meticulously planned its EHV Distribution Network for intra sub-

station transfer of power. A 220kV ring interconnecting all the seven 220kV sub

stations in the HP system in a phased manner is proposed alongwith construction

of 400kV transmission line from Nalagarh (PGCIL’s sub-station to link Nalagarh) to

Kunihar with 400/220kV sub-station at Nalagarh. This 220kV ring along with

400kV system will strengthen the existing power delivery system in a big way to

the extent of 500 MW from one corver to another corner in the State within

minimum lines.

9.1.4 EHV Distribution Schemes (66kV & above) - BADP-13th FINANCE COMMISSIION

GRANTS:

9.1.4.1 An outlay of Rs. 3.00 Cr. has proposed for construction of 22 KV main line from

Pooh to Kaza on 66KV Towers (in sliding zone) under BADP-13th Finance

Commission subject to actual by GoHP.


Nov, 2013 Page | 41

9.1.5 Distribution Schemes 33kV & below (Project Finance Mode)

9.1.5.1 The improvement of HV & LV Distribution System has been planned in the

following manner:

A. Rural electrification and RE & system Improvement Plans: The focus is to cover remaining areas including all villages, households and hemlets and strengthening of existing unwieldy lengthy HV/LV network. RE & System Improvement plans emphasis shall be given on strengthening the Sub-Transmission and Distribution System for mitigating the low voltage problem through various schemes like: a) 33kV new Substations and its associated lines b) Augmentation of 33kV Sub Stations c) Renovation & Modernization of 33/22/11kV Substations equipment d) HVDS, replacement of meters, poles, GI Wire etc.

B. Consumer Service and Electrification (Circle-wise): For consumer services & intensive electrification in the areas falling under the respective Operation Circles, following activities are proposed to be undertaken during the Control Period a) 11/22kV new lines augmentation & re-organization. b) New DTRs 11/.4kV 22/.4kV & 33kV augmentation& new capacitor banks

etc. c) New LT, augmentation, re-organization/conversion of LT to HT d) New Service connection. e) Replacement, augmentation, re-organization or services f) Metering of LT & HT g) Any major T&P

C. Centrally Sponsored Schemes (RGGVY & APDRP Part-B): At present, two such flagship schemes sponsored by Govt. of India are underway in HPSEB Ltd., which are described briefly hereunder:

a) RGGVY Schemes RGGVY was launched in April, 2005 with the aim to electrify all un-

electrified villages/habitations & provide access to electricity in every

households having provision of 90% capital subsidy & 10% loan. HPSEBL

formulated District-wise electrification schemes under RGGVY as per

guidelines of REC. Implementation of these schemes would ensure

reliable and quality power supply to 44496 rural households including

12483 BPL households to be provided access to electricity free of cost.

These schemes also envisage strengthening of Distribution System in

rural areas of all the 12 Districts by providing 2092 new Distribution Sub

Stations of adequate capacity and lines. The RGGVY Schemes covering

all the 12 Districts has been approved by REC, GoI worth Rs. 341.00 Cr.,


Nov, 2013 Page | 42

out of which Rs.319.00 Cr. shall be under 90% assistance. These works

have been undertaken in all the 77 blocks of the Pradesh and works in

71 blocks are complete and in remaining 6 blocks works shall be

completed by December, 2013.

b) R-APDRP – Part-B Schemes Under R-APDRP scheme launched by GOI, the Towns of Himachal

Pradesh with population more than 10000 has been covered for

improvement of power delivery infrastructure. The major works

proposed are new 66kV, 33kV, 22kV, 11kV lines and 66/11kV, 66/33kV,

66/22kV, 33/11kV Sub-stations. The Power transformers having loading

more than 70% has been proposed to be augmented; the lengthy HT/LT

lines has been proposed to be reduced by installing new DTRs. To

facilitate spotting of faults Provision of Fault passage Indicators (FPIs)

has been made for easy identification of faulty phase.

For HP, 14 towns namely, Nahan, Paonta Sahib, Shimla, Baddi, Bilaspur,

Chamba, Dharamshala, Hamirpur, Kullu, Mandi, Sundernagar, Una & Yol

have qualified the criteria laid down and schemes worth Rs.322.00 Cr.

have been approved by GoI. 90% of the outlays, which shall be available

as a loan in the first instance, shall be converted into grant, if HPSEB

Ltd. is able to adhere to time lines specified for the purpose. Now the

schemes have been revised to Rs.589.47 Cr. An outlay of Rs. 149.47 Cr.

has been proposed for FY 13-14.

D. GOHP Schemes: a) Tribal Area Sub Plan:

An outlay of Rs. 3.25 Cr. has been kept as token provision under this Tribal Sub Plan for FY 13-14, which is 100% aided by GoHP.

b) Scheduled Cast Sub Plan: An outlay of Rs. 4 Cr. has been kept as token provision under this plan for FY 13-14 subject to actual grant by GoHP.

9.1.6 ALDC, system operation, communication systems etc:

a. ALDC, System Operation, Communication System – Major Capital Works: An outlay of Rs. 0.55 Cr. has been proposed for up- gradation & establishment of

ALDC, System Operations & Communication System for FY 2013-14.

b. ALDC, System Operation, Communication System – Minor Capital Works: For minor capital works to be undertaken under exigent conditions a lump-sum

individual provision of outlay worth Rs.0.31 Cr. has been proposed during the FY

2013-14.


Nov, 2013 Page | 43

9.1.7 Minor Capital Works (Indivisibles Allocation):

9.1.7.1 For minor capital works, lump-sum indivisible provisions (outlays) are proposed

for which block funding shall be arranged Circle-wise in a consolidated.

Accordingly, an outlay of Rs 4.00 Cr has been proposed in EHV works and of Rs. 8

Cr. has been proposed for distribution works below 33 kV for FY 2013-14.

9.1.8 New Buildings:

9.1.8.1 HPSEB Ltd. is facing great difficulty in the absence of its own buildings both

residential as well as non-residential. This problem has further aggravated in view

of the increased activities of the Board. For the last many years outlay have been

very less. Housing has assumed importance at the National level. In order to

provide proper accommodation to the staff of the Board at all places as also the

office accommodation it is necessary that liberal provision of funds should be

made under this head. However, keeping in view the financial constraints as

HPSEB Ltd. has to depend only upon borrowing for the purpose, an outlay of

Rs.5.00 Cr. has been proposed for this purpose during the FY 2013-14.

9.1.9 IT PROJECTS:

9.1.9.1 HPSEBL has undertaken main IT initiatives to improve efficiency and bring about

greater transparency in its operations. HPSEBL has successfully implemented

several projects and proposes to build on the backbone already established to

implement new and innovative technologies to provide quality power and

services, while simultaneously taking steps to improve revenue buoyancy and

higher collection efficiency.

To fund the existing programs as well as new initiatives HPSEBL has proposed the

following capex for 3rd MYT control period.

9.1.10 The summary of the planned capex investment for above schemes could be found

in the following table. The proposed investment in the FY 18 and FY 19 has been

tentatively proposed as the HPSEBL is currently under process for detailed

schemewise capex preparation.

9.2. Capital investment plan for Generation Schemes

9.2.1 Generation Schemes – Provision for Completed Projects.

At present 23 power houses with aggregated installed capacity of 477.45 MW are

in operation under HPSEB Ltd. Some of these projects are even almost century old


Nov, 2013 Page | 44

and most of them are more than two/three decades old which requires

repairs/capital maintenance which need to undertaken under Capital Head being

major works in respect of electromechanical components or the civil structure of

these projects. Accordingly, the works on the following projects are slated to be

undertaken during FY 13-14 and completion of these works during the MYT Control

Period FY 2014-19 is proposed.

(i) Larji (ix) Bassi

(ii) Khauli-I (x) Binwa

(iii) Thirot (xi) Gaj

(iv) Bhaba (xii) Andhra

(v) Ghanvi-I (xiii) RongTong

(vi) Rukti (xvi) Chaba

(vii) Gumma

9.2.1.1 An outlay of Rs. 31.83 Cr. is proposed for such works during FY 13-14.

9.2.2 Generation Schemes – Renovation & Modernization:

9.2.2.1 Renovation & Modernization LE works on 6 No. Power Houses under operation

namely (i) Bhabha , (ii) Bhabha Aug, (iii) Rong Tong, (iv) Rukti, (v) Giri and (vi) Gaj

are under way or shall be taken for extensively RM &LE during the MYT Control

Period FY 2014-19.

9.2.2.2 An outlay of Rs. 22.45 Cr. has been proposed for FY 2013-14 for the purpose.

9.2.3 Generation Schemes under Tribal Area Sub Plan – 13th Finance Commission Grants

for R&M

9.2.3.1 HPSEBL is carrying out R&M works on two of the projects located in Tribal Area

namely (i) Rongtong (2MW) and (ii) Rukti (1.5MW) under Grant from Tribal

Department, GoHP. Accordingly, outlay worth Rs. 4.87 Cr. is proposed for FY

2013-14 to carryout R&M works of these projects subject to actual by GoHP.

9.2.4 Below mentioned is the scheme wise CAPEX plan to be done by HPSEBL for the 3rd

Control Period:

Table 39: Scheme Wise CAPEX Plan

Heads FY 2014 FY 2015 FY 2016 FY 2017 FY 2018 FY 2019

EHV Works 134.6 366.9 371.4 296.4 291.9 227.4

Distribution Schemes - OP North

35.2 101.6 36.3 41.4 45.0 37.2


Nov, 2013 Page | 45

Distribution Schemes - OP Central

30.9 64.5 40.2 24.9 21.6 10.4

Distribution Schemes - OP South

43.7 56.8 51.2 50.3 42.1 36.2

Consumer Services & Electrification Schemes

47.0 100.6 93.9 118.0 124.0 125.3

Centrally Sponsored Schemes

140.3 157.8 60.4 19.5 15.4 15.5

IT Works 99.5 68.5 79.7 86.1 80.4 66.8

GoHP Schemes 0.7 3.3 6.4 5.6 4.8 3.5

New Buildings 4.8 7.8 14.0 13.0 9.6 8.9

Minor works 9.4 12.5 13.4 16.1 17.0 18.8

ALDC Works 1.2 0.5 18.0 23.5 0.0 0.0

Total CAPEX 547.4 940.8 784.7 694.9 651.8 550.0

9.3. Phasing of capital expenditure

While the generation schemes have been captured in the calculation of the AFC of

the generation plants, the following table gives the plan for distribution capex.

This shall subsequently become a part of the ARR for HPSEBL.

Table 40: CAPEX summary

Capex details (Rs. Cr.) FY 2014 FY 2015 FY 2016 FY 2017 FY 2018 FY 2019

Opening CWIP 353 858 815 1244 1550 1801

Addition during the year 547 941 785 695 652 550

Capitalized during the year (incl IDC)

44 983 355 389 401 2351

Closing CWIP 858 815 1244 1550 1801 0

Opening GFA 0 44 1028 1383 1772 2173

Addition during the year, incl IDC

44 983 355 389 401 2351

Closing GFA 44 1028 1383 1772 2173 4524

Opening GFA 0 43 756 1112 1449 1849

Addition during the year, incl IDC (excl grants)

43 713 355 337 401 2275

Closing GFA 43 756 1112 1449 1849 4125


Nov, 2013 Page | 46

Table 41: Funding summary

Funding of CAPEX (Rs. Cr.) FY 2014 FY 2015 FY 2016 FY 2017 FY 2018 FY 2019

Opening debt 312 691 1405 2051 2597 3054


Debt repayment 2 6 9 61 116 183

Closing debt 691 1405 2051 2597 3054 3353

Interest 4 64 120 157 198 413

IDC 66 125 135 174 208 215

Opening Equity 0 4 72 107 140 179


Closing Equity 4 72 107 140 179 394

Opening Grant 0 1 271 271 324 324


Closing grant 1 271 271 324 324 399


Nov, 2013 Page | 47

10. ESTIMATION OF ARR

Following sections outlines the Aggregate Revenue Requirement of HPSEBL for 3rd Control

Period (FY 2014-15 to FY 2018-19) considering the actual provisions performance in previous

3 years, provisional latest available information for FY 2013-14 projected for balance period

of FY 2013-14 and projections for FY 2014-15 to FY 2018-19 and Provisions of HPERC MYT

Regulations, 2013.

The components for the calculation of total expenses for the ARR Petition for the 3rd Control

Period are as follow:

Power Purchase Cost

Operation & Maintenance Cost

Interest on Loan and Financial Charges

Interest on Working Capital

Provision for Bad Debts

Return on Equity

Non Tariff Income

10.1. Operation & Maintenance Expenses

Operations and Maintenance (O&M) Expenses of HPSEBL consists of the following elements:

Repairs and Maintenance Costs

Employee Expenses

Administrative and General Expenses

10.1.1 Repairs and Maintenance Cost

These expenses include expenses on repairs and maintenance of Plant and

Machinery, Transformers, Building, Other Civil Works, Hydraulic works, Lines, cable

network etc., Vehicles, Furniture & fixtures, Office equipment, etc.

As per the HPERC (Terms and Conditions for Determination of Wheeling Tariff and

Retail Supply Tariff) Regulations, 2011 along with Amendment 1, 2012 and

Amendment 2, 2013, the R&M cost has to be calculated as:

R&Mn = K x GFAn-1x WPIinflation

‘K’ - is a constant (could be expressed in %). The calculation of K is presented below:


Nov, 2013 Page | 48

Table 42: K factor calculation

Rs. Crs

Particulars FY 11 FY 12 FY 13

Opening GFA 2424.56 2345.07 3226.58

Closing GFA 2475.25 3226.58 3803.16

Average GFA 2449.91 2785.83 3514.87

GFA added during the year 116.32 881.51 576.58

R&M Costs as % of GFA 1.14% 1.09% 0.92%

K factor 1.05%

‘WPIinflation’ – is the average increase in the Wholesale Price Index (WPI) for

immediately preceding three years before the base year; The same has been

calculated below:

Table 43: WPI

FY WPI Index Growth (WPI)

2009-2010 130.82

2010-2011 143.33 9.56

2011-2012 156.13 8.94

2012-2013 167.58 7.33

Average

8.61

Source:http://www.eaindustry.nic.in/wpi_data_display/display_data.asp

‘R&Mn’ – Repair and Maintenance costs of the transmission licensee for the nth year;

‘GFAn-1’ – Gross Fixed Asset of the transmission licensee for the n-1th year;

For calculating the R&M cost of the nth year, the GFA addition of that year has also

been considered and the same has been multiplied with the K factor (excluding

inflation, as it is assumed the GFA addition of that year is on current year prices)

Using the above mentioned methodology, the R&M expenses for the control period

are given in the table below:

Table 44: R&M Expenses

Particulars FY 14 FY 15 FY 16 FY 17 FY 18 FY 19

Rs Cr. RE Proj. Proj. Proj. Proj. Proj.

Plant & Machinery 0.05 0.06 0.07 0.07 0.08 0.11

Buildings 1.77 2.24 2.28 2.56 2.79 3.85

Civil Works 0.61 0.77 0.79 0.88 0.96 1.33

Hydraulic Works 0.01 0.01 0.01 0.01 0.02 0.02

Lines, Cables Networks 64.54 81.61 83.19 93.38 101.61 140.29

Vehicles 13.80 17.45 17.79 19.97 21.73 30.00

Furniture & Fixtures 0.04 0.05 0.06 0.06 0.07 0.09

Office Equipments 1.13 1.43 1.46 1.64 1.78 2.46

R&M Cost – Total 81.96 103.63 105.65 118.58 129.04 178.16

http://www.eaindustry.nic.in/wpi_data_display/display_data.asp


Nov, 2013 Page | 49

Any other Items (Reallocated to Capital Works) -3.30 -4.17 -4.25 -4.77 -5.19 -7.16

R&M Costs after Capitalization 78.66 99.47 101.40 113.81 123.85 171.00

Less: Cost Reallocated to Employee Cost & A&G Expenses

23.50 29.71 30.29 33.99 36.99 51.08

Less: Cost Reallocated to Depreciation & Recovery of cost of vehicle from O&M and other units

14.13 17.87 18.21 20.44 22.25 30.71

Overall R&M Expenses 41.04 51.89 52.90 59.38 64.61 89.21

10.1.2 Employee Cost

As per the Tariff regulations, the employees’ expenses have been calculated as per

the following formulae

EMPn = [(EMPn-1) x (1+Gn) x (CPIinflation)] + Provision(Emp)

Where:

‘CPIinflation’ – is the average increase in the Consumer Price Index (CPI) for

immediately preceding three years before the base year;

The CPIinflation rate is calculated as per the following table

Table 45: CPI

FY CPI Index Growth in CPI

2009-2010 162.75

2010-2011 179.75 10.45%

2011-2012 194.83 8.39%

2012-2013 215.17 10.44%

Average

9.76%

Source: http://labourbureau.nic.in/indtab.pdf

‘EMPn-1’ – employee’s cost of the transmission licensee for the (n-1)th year.

‘Provision(Emp)’- Provisions and expected one-time expenses as specified above;

‘Gn’ - is a growth factor for the nth year. Value of Gn shall be determined by the

Commission in the MYT tariff order for meeting the additional manpower

requirement based on licensee’s filings, benchmarking, approved cost by the

Commission in past and any other factor that the Commission feels appropriate;

The growth rate in employees has been calculated based on the number of

consumers handled per employee within the state. It is assumed that the number of

consumers handled per employee shall increase at a rate of 3% annually during the

MYT period. Accordingly, the growth (Gn) in number of employees has been

calculated as below:

http://labourbureau.nic.in/indtab.pdf


Nov, 2013 Page | 50

Table 46: Growth factor for employee costs

FY 13 FY 14 FY 15 FY 16 FY 17 FY 18 FY 19

Actuals RE Proj. Proj. Proj. Proj. Proj.

Number of Employees 19357 19917 19833 19752 19673 19597 19523

Growth (G) % in Employees on Account of Consumer connections

2.89% -0.42% -0.41% -0.40% -0.39% -0.38%

As per the projected values of Gn and CPIinflation , the employee expenses calculated

for the 3rd Control Period for HPSEB are as follows:.

Table 47: Employee Expenses for 3rd Control Period (Rs. Crs)



Salaries (Basic) 335.6 366.8 400.9 438.3 479.2 523.9

Grade pay 82.3 90.0 98.4 107.5 117.6 128.5

DA 266.5 291.3 318.4 348.1 380.6 416.1

Arrears of previous years 0.0 0.0 0.0 0.0 0.0 0.0

Other Allowances 35.3 38.6 42.2 46.1 50.4 55.1

Overtime 2.8 3.1 3.4 3.7 4.0 4.4

Bonus 0.0 0.0 0.0 0.0 0.0 0.0

Total Salaries 724.1 791.4 865.0 945.6 1033.9 1130.5

Other Staff Cost 0.0 0.0 0.0 0.0 0.0 0.0

Incentives/Awards 0.2 0.2 0.2 0.3 0.3 0.3

Incentives/Awards 1.6 1.7 1.9 2.0 2.2 2.4

Earned Leave Encashment 93.3 101.9 111.4 121.8 133.2 145.6

Medical Expense Re-Imbursement 10.0 10.9 11.9 13.0 14.3 15.6

Leave Salary Contribution 0.0 0.0 0.0 0.0 0.0 0.0

Payment Under Workman’s Compensation And Gratuity

1.2 1.3 1.4 1.5 1.7 1.8

Staff Welfare Expenses 0.4 0.4 0.4 0.5 0.5 0.6

Gross Other Staff Cost 106.6 116.5 127.3 139.2 152.2 166.4

Terminal Benefits 530.4 556.9 584.8 614.0 644.7 676.9

Gross Employee Cost 1361.0 1464.8 1577.1 1698.8 1830.8 1973.8

Chargeable To Construction Works 39.9 43.6 47.6 52.1 56.9 62.2

Net Employee Cost 1321.2 1421.2 1529.5 1646.8 1773.9 1911.6

10.1.3 Administrative and General Expenses

A&G Expenses during the 3rd Control Period have been projected on the basis of the

methodology as per MYT Regulations of the Commission.

In the Second Amendment to the MYT tariff regulations of 2013, the norms for A&G

costs needs to be decided based on - combination of A&G expense per personnel and

A&G expense per 1000 consumers for A&G expenses


Nov, 2013 Page | 51

The norms have been calculated based on the following table:

Table 48: A&G norms

Norms FY 13

Actuals

No. of employees 19357

A&G cost (Rs Cr.) 41.5

A&G / employee (Rs '000 / employee) 21.4

No. of consumers 2,087,604

A&G cost (Rs. Cr.) 41.5

A&G / 1000 consumers (Rs '000 / 1000 consumers) 198.8

The projections for number of employees and consumers are presented in the

following table. These projections, along with the WPI inflation as calculated in the

previous section would be used to estimate the A&G costs during the Control Period

Table 49: Projections for applying A&G norms

FY 14 FY 15 FY 16 FY 17 FY 18 FY 19

Proj. Proj. Proj. Proj. Proj. Proj.

No. of employees 19,917 19,833 19,752 19,673 19,597 19,523

No. of consumers 2,140,983 2,195,939 2,252,542 2,310,858 2,370,959 2,432,922

Weightage of A&G/ Employee 50.00%

Weightage of A&G/ 1000 Consumers 50%

WPI 8.61%

Based on the methodology discussed above, A&G Expenses for the 3rd Control period

have been projected as below:

Table 50: A&G Expenses for 3rd Control Period (Rs. Crs)



Rent, Rates & Taxes 0.9 1.0 1.1 1.2 1.3 1.4

Telephone, Postage & Telegrams 2.9 3.1 3.5 3.8 4.2 4.6

Consultancy Charges 0.8 0.9 1.0 1.1 1.2 1.3

Conveyance & Travel 16.6 18.2 20.0 22.0 24.2 26.6

Regulatory Expenses 1.3 1.4 1.6 1.7 1.9 2.1

Income Tax Updating Charges 0.0 0.0 0.0 0.0 0.0 0.1

Consumer Redressal Forum & Ombudsman 0.1 0.1 0.1 0.1 0.1 0.1

Insurance 0.1 0.2 0.2 0.2 0.2 0.2

Purchase Related Expenses & Other Charges 0.4 0.4 0.4 0.5 0.5 0.6

Administration Charges - Total 23.1 25.4 27.9 30.6 33.6 37.0

Other Charges

Fees & Subscriptions, Books & Periodicals 0.3 0.3 0.4 0.4 0.4 0.5

Printing & Stationery 0.8 0.9 1.0 1.1 1.2 1.3

Advertisement Expenses 0.4 0.4 0.5 0.5 0.6 0.6

Donation/ Contribution 0.0 0.0 0.0 0.0 0.0 0.0


Nov, 2013 Page | 52

Electricity Charges 3.4 3.7 4.1 4.5 4.9 5.4

Water Charges / Cold weather expenses 0.3 0.4 0.4 0.4 0.5 0.5

Miscellaneous Expenses 2.7 3.0 3.3 3.6 4.0 4.4

Legal Charges 0.8 0.9 1.0 1.1 1.2 1.3

Audit Fee/Statutory Audit Fee 0.3 0.3 0.3 0.4 0.4 0.4

Freight Material related Expenses 3.0 3.3 3.6 4.0 4.3 4.8

Entertainment Charges 0.2 0.2 0.3 0.3 0.3 0.3

Training to Staff 0.1 0.1 0.1 0.1 0.1 0.1

Public Interaction Program 0.2 0.6 0.6 0.7 0.8 0.9

Public Expenses / Other professional charges 0.0 0.0 0.0 0.0 0.0 0.0

GIS / GPS expenses related to High level Committee

1.0 1.0 1.2 1.3 1.4 1.5

Expense for providing cost free CFL bulbs to domestic consumers

12.2 13.4 14.7 16.1 17.7 19.5

Fee for SSA Examination 0.0 0.0 0.0 0.0 0.0 0.0

A&G – Total 49.4 54.6 59.9 65.8 72.4 79.6

Less: Capitalization 3.1 3.4 3.7 4.1 4.5 4.9

Net A&G Costs 46.3 50.8 55.8 61.3 67.4 74.0

10.2. Depreciation

Depreciation has been calculated taking into consideration the opening balance of

assets in the beginning of the year and the projected capitalization. Assets funded

through grants have been excluded in the calculation of depreciation. The

Depreciation rates used as per the HPERC MYT Tariff regulations. The estimated

depreciation for the 3rd Control Period is shown in the following tables:

Table 51: Asset details for depreciation calculations

Particulars FY 14 FY 15 FY 16 FY 17 FY 18 FY 19 Rate of

Rs Cr. RE Proj. Proj. Proj. Proj. Proj. Dep

Land & Land Rights 70.5 85.9 94.1 102.0 111.4 159.0 0.0%

Building & civil works 121.2 171.9 198.9 225.0 255.6 412.2 1.8%

Hydraulic Works 16.9 19.9 21.5 23.0 24.8 34.0 5.3%

Towers, Poles, Fixture, overhead, conductors devices

1587.1 1843.2 1979.4 2111.0 2265.6 3056.4 3.6%

Switchgears, control gears & protection

598.7 721.9 787.4 850.7 925.1 1305.6 3.6%

Plants & Machinery 1258.0 1459.7 1567.0 1670.7 1792.5 2415.4 3.6%

Vehicles 14.5 18.4 20.4 22.4 24.8 36.7 18.0%

Furniture Fixture 7.5 9.6 10.8 11.9 13.2 19.8 6.0%

Office equipments incl intangibles 31.8 36.4 38.8 41.2 44.0 58.1 6.0%

Assets not belonging to the Board 3.1 3.9 4.3 4.6 5.1 7.4

Others civil works 171.1 265.9 316.3 365.1 422.3 715.1 1.8%

Total 3880.5 4636.7 5039.1 5427.6 5884.3 8219.7

Assets not in use 5.2 0.0 0.0 0.0 0.0 0.0


Nov, 2013 Page | 53

G. Total 3885.7 4636.7 5039.1 5427.6 5884.3 8219.7

Table 52: Depreciation for 3rd Control Period (Rs. Crs)


Rs Cr. Proj. Proj. Proj. Proj. Proj. Proj.

Depreciation 133.8 143.8 155.8 167.2 180.7 249.6

10.3. Interest & Finance Charges

10.3.1 Interest on new and existing loans

Based on the capital investment plan, the interest charges for the new and existing

loans to be taken are calculated in the table below:

Table 53: Interest on new & existing loans

Details of Loan/ interest Payments FY 14 FY 15 FY 16 FY 17 FY 18 FY 19

RE Proj Proj Proj Proj Proj

Opening Balance 2,380.3 2,760.9 3,289.8 3,743.6 4,130.2 4,299.7

Addition 791.1 719.6 654.9 607.6 572.6 482.2

Repayment 410.5 190.7 201.1 221.0 403.1 409.3

Closing Balance 2,760.9 3,289.8 3,743.6 4,130.2 4,299.7 4,372.6

Interest & Financing Charges 332.70 472.70 517.62 573.65 673.19 820.62

Less: Interest Capitalization 66.07 125.27 135.06 174.38 208.19 215.40

Net: Interest & Financing Charges 266.63 347.43 382.56 399.27 465.00 605.22

10.3.2 Interest on working capital

The interest on working capital has been calculated as per HPERC (Terms and

Conditions for Determination of Wheeling Tariff and Retail Supply Tariff) Regulations,

2011 along with Amendment 1, 2012 and Amendment 2, 2013.

As per the above, working capital for the retail supply business is calculated as below:

a. O&M expenses for one month;

b. receivables for two months of the wheeling charges;

c. maintenance spares @ 40% of R&M Expenses for one month; and

Less

d. consumer security deposit, if any.

As per Amendment 2 of 2013, the working capital interest rate shall be equal to - the

average base rate of the last six months prior to the filing of the MYT petition plus 350

basis points. The average base rate of SBI for the past 6 months is 9.8%. Adding 350

basis points to the same, the working capital rate of interest becomes 13.3%.

The calculations for working capital interest cost are presented in the following table


Nov, 2013 Page | 54

Table 54: Interest on working capital

2013-14 2014-15 2015-16 2016-17 2017-18 2018-19


O&M expenses 1451.5 1571.2 1690.0 1824.0 1967.8 2142.7

R&M expenses 41.0 51.9 52.9 59.4 64.6 89.2

A&G expenses 49.4 54.6 59.9 65.8 72.4 79.6

Employee expenses 1361.0 1464.8 1577.1 1698.8 1830.8 1973.8

O&M expenses for 1 month 121.0 130.9 140.8 152.0 164.0 178.6

Annual revenues from tariffs and charges

4443.6 4771.1 5312.9 5597.4 5921.2 6407.4

Receivables equivalent to 2 months average billing

740.6 795.2 885.5 932.9 986.9 1067.9

Maintenance Spares (40% of R&M Expense of 1 Month)

1.4 1.7 1.8 2.0 2.2 3.0

Less: Consumer Security Deposit (CSD)

256.1 262.7 269.5 276.4 283.6 291.0

Total Working Capital 606.8 665.2 758.6 810.5 869.4 958.4

Interest on Working Capital 80.7 88.5 100.9 107.8 115.6 127.5

10.3.3 Overall interest and finance charges

In addition to the above interest charges, the interest and finance costs for existing

loans, etc have been projected based on historical trends. The overall interest and

finance charges for the Control Period have been projected in the following table:

Table 55: Total interest and finance charges

2014-15 2014-15 2015-16 2016-17 2017-18 2018-19

INR Cr Proj. Proj. Proj. Proj. Proj. Proj.

RGGVY 3.3 3.0 2.7 2.4 2.1 1.8

LIC 11.5 9.5 7.5 5.3 3.3 2.0

REC - Existing loans as on 31 march 2013

92.2 83.3 74.5 65.7 57.0 48.4

PFC 0.1 0.1 0.1 0.0 0.0 0.0

Short Term Bank Loans as per FRP Restructuring Plan

104.4 122.5 115.8 108.0 144.2 80.9

Non SLR Bonds 20.8 26.7 24.5 23.3 23.3 23.3

Other Negotiated Loan 0.0 0.0 0.0 0.0 0.0 0.0

Cost of Raising Finances 7.6 14.4 13.1 12.2 11.5 9.6

Interest on Consumer Deposits 23.0 23.6 24.3 24.9 25.5 26.2

Interest on new CAPEX loans 69.8 189.6 255.3 331.9 406.3 628.4

Interest on WC Borrowings 80.7 88.5 100.9 107.8 115.6 127.5

Interest & Finance Charges - Total 413.4 561.2 618.5 681.4 788.8 948.1


Nov, 2013 Page | 55

10.4. Provision for bad and doubtful debts

Certain amount of receivables for HPSEBL remains unpaid. Hence, to account for such

cases, HPSEBL has made a provision for bad and doubtful debts.

The average provision of the pending receivables for HPSEBL has been 0.7%. The

same has been used for forecasting the provision for bad and doubtful debts for the

Control Period.

Table 56: Provision for Bad and Doubtful Debt for last 3 years (Rs. Crs)

Particulars PY PY PY

2010-11 2011-12 2012-13

Actual Actual Actual

Receivables 292.15 487.67 411.59

% of provision 0.48% 0.29% 1.33%

Average of % for bad debts 0.70%

Based on the projected receivables from live and permanently disconnected consumers and

the percentage provision as calculated above, the following table gives the provision for bad

and doubtful debt during the Control Period.

Table 57: Provision for Bad and Doubtful Debt for 3rd Control Period (Rs. Crs)



Receivable from customers as at the beginning of the year

417.3 438.94 469.48 518.92 551.58 584.01

Revenue billed for the year 4443.6 4771.1 5312.9 5597.4 5921.2 6407.4

Collection for the year

Against current dues 4088.1 4389.4 4887.8 5149.6 5447.5 5894.8

Against arrears upto previous year 333.8 351.2 375.6 415.1 441.3 467.2

Gross receivable from customers as at the end of the year

438.9 469.5 518.9 551.6 584.0 629.4

Receivables against permanently disconnected consumers

6.3 6.3 6.3 6.3 6.3 6.3

Receivables 432.6 463.2 512.6 545.3 577.7 623.1

% of provision 0.70% 0.70% 0.70% 0.70% 0.70% 0.70%

Provision for bad and doubtful debts 3.0 3.2 3.6 3.8 4.1 4.4

10.5. Non tariff income

Non tariff income for HPSEBL accrues essentially from meter rent, miscellaneous

recoveries from consumers including delayed payment surcharge, recovery of


Nov, 2013 Page | 56

wheeling charges, O&M charges recoverable from HPPTCL for the maintenance of

their transmission lines, etc.

For all the items in the non-tariff income, an annual inflation of 5% is assumed. In

addition, the rationale for projections of various non-tariff items is as follows:

a) Income from meter rent has been projected to grow at the same rate as the

number of consumers

b) Recovery of theft, Wheeling Charges and Miscellaneous Charges have been

projected to grow at the same rate as the growth in unit sales of electricity

c) Interest on staff loan has been assumed to increase at the rate of employee

growth rate

d) Delayed payment charges have been assumed to grow at a rate equal to the

revenue growth

e) Interest on advances to suppliers has been projected to grow in proportion to the

capital investment

f) Income from trading has been assumed to grow at a rate equal to the growth in

MU sales

g) PLVC charges are proposed to be abolished and hence no income has been

considered for the same

h) O&M Charges recovery from HPPTCL is based on the CERC guidelines and the

inflation rate of 5.72%; this is because the payment from HPPTCL is calculated on

CERC norms

i) Miscellaneous Receipts have been assumed to remain constant at current levels

in view of no concrete basis of projections.

The following table presents the projected non-tariff income for HPSEBL

Table 58: Non Tariff Income for 3rd Control Period (Rs. Crs)

Particulars FY 11 FY 12 FY 13 FY 14 FY 15 FY 16 FY 17 FY 18 FY 19

Rs Cr. Actuals Actuals Actuals RE Proj. Proj. Proj. Proj. Proj.

Meter Rent/Service Line Rentals

31.6 36.8 41.4 44.6 48.0 51.7 55.7 60.0 64.7

Recovery for theft of Power / Malpractices

0.0 0.0 0.1 0.1 0.1 0.1 0.1 0.1 0.1

Wheeling Charges Recovery 43.1 64.4 81.3 89.0 98.6 109.3 121.2 134.4 149.1

Miscellaneous Charges from Consumers

8.7 5.4 5.6 7.2 8.0 8.8 9.8 10.9 12.1

Non Tariff Income - Total 83.4 106.6 128.4 140.8 154.6 169.9 186.8 205.4 225.9

Other Income

Interest on Staff loans & Advances

0.5 1.3 0.5 0.5 0.5 0.5 0.5 0.5 0.5

Income from Investments 7.1 28.0 18.2 19.2 20.1 21.1 22.2 23.3 24.4


Nov, 2013 Page | 57

Delayed Payment Charges from Consumers

14.2 18.8 29.9 31.5 33.8 37.7 39.7 42.0 45.4

Interest on Advances to Suppliers / Contractors

0.1 0.2 0.3 0.5 0.8 0.7 0.6 0.5 0.5

Income from Trading 1.0 0.8 1.7 1.7 1.8 1.9 2.0 2.1 2.3

Miscellaneous Receipts 60.1 63.8 77.1 67.0 67.0 67.0 67.0 67.0 67.0

O&M Charges Recovery from HPPTCL

0.0 0.0 0.0 6.4 6.8 7.2 7.6 8.0 8.5

PLVC charges 30.7 30.3 35.1 36.1 0.0 0.0 0.0 0.0 0.0

Gain on sale of fixed assets 0.0 0.3 0.0 0.0 0.0 0.0 0.0 0.0 0.0

Other Income - Total 113.8 143.6 162.8 163.0 131.0 136.2 139.7 143.6 148.7

Total Non Tariff Income & Other Income

197.2 250.2 291.2 303.8 285.6 306.1 326.4 349.0 374.6

10.6. Return on equity

As per HPERC (Terms and Conditions for Determination of Wheeling Tariff and Retail

Supply Tariff) Regulations, 2011 read along with Amendment 1, 2011 and

Amendment 2, 2013, the Return on equity for the distribution licensee (sum of return

on equity for wheeling business and return on retail supply business) shall be

computed on the paid up equity capital and shall be 16% per annum (post tax):

For the control period, the same has been calculated on the average equity during a

year at 16% post-tax ROE. This 16% pre-tax equity ROE rate becomes 24.24% pre-tax.

The return on equity is shown in the table below:

Table 59: Return on equity



Opening Equity 229.00 293.3 361.4 396.2 429.1 468.4

Equity Infusion 64.32 68.0 34.8 32.9 39.3 214.5

Closing Equity 293.32 361.4 396.2 429.1 468.4 682.9

Rate of Return on Equity 16.00% 16.00% 16.00% 16.00% 16.00% 16.00%

Return on Equity 41.79 52.4 60.6 66.0 71.8 92.1

10.7. ARR summary

Based on the discussion in the above chapters of the parameters constituting the ARR

of HPSEBL, the following table gives the ARR summary:


Nov, 2013 Page | 58

Table 60: Annual Revenue Requirement for 3rd Control Period (Rs. Crs)

Particulars FY 14 FY 14 FY 15 FY 16 FY 17 FY 18 FY 19

Rs Cr. Approved RE Proj. Proj. Proj. Proj. Proj.

Purchase of Power from Own Stations

2274.2 295.3 328.7 488.9 505.2 544.4 559.0

Purchase of Power from Other Sources (Including UI) 2111.5 2477.0 2726.6 3017.7 3365.4 3924.4

Transmission Charges 248.5 266.8 372.9 424.5 476.9 558.5 670.2

R&M Expense 36.5 41.0 51.9 52.9 59.4 64.6 89.2

Employee Expenses 1070.1 1361.0 1464.8 1577.1 1698.8 1830.8 1973.8

A&G Expense 42.3 49.4 54.6 59.9 65.8 72.4 79.6

Depreciation 109.0 133.8 143.8 155.8 167.2 180.7 249.6

Interest & Finance Charges 121.2 413.4 561.2 618.5 681.4 788.8 948.1

Less: Interest & other expenses capitalized -48.1 -109.0 -172.2 -186.4 -230.5 -269.6 -282.6

Other Debits (incl. Prov for Bad debts) 0.0 3.0 3.2 3.6 3.8 4.1 4.4

Extraordinary Items ( True Up / carrying cost for FY 13) 725.2 0.0 801.4 0.0 0.0 0.0 0.0

Total 4578.8 4566.4 6087.3 5921.4 6445.8 7140.1 8215.8

Reasonable Return 30.2 41.8 52.4 60.6 66.0 71.8 92.1

Other Income 309.2 303.8 285.6 306.1 326.4 349.0 374.6

Annual Revenue Requirement 4299.9 4304.4 5854.0 5676.0 6185.4 6863.0 7933.3

Revenue from existing tariffs 4444 4771 5313 5597 5921 6407

Surplus / (Gap) 139 -1083 -363 -588 -942 -1526

10.7.1 ARR for Wheeling and Retail Supply Business

Based on the approved segregation mechanism of the HPERC, the overall ARR has

been divided into Wheeling and Retail Supply in the following tables:

Table 61: Wheeling ARR for 3rd Control Period (Rs. Crs)

Wheeling ARR FY 14 FY 15 FY 16 FY 17 FY 18 FY 19


Power Purchase Expenses 0.0 0.0 0.0 0.0 0.0 0.0

Transmission Charges 0.0 0.0 0.0 0.0 0.0 0.0

Employee Expenses 952.7 1025.3 1104.0 1189.2 1281.6 1381.7

R&M Expenses 36.9 46.7 47.6 53.4 58.2 80.3

A&G Expenses 29.5 32.4 35.6 39.1 43.0 47.2 Interest & Financing Charges (other than interest on working capital)

332.7 472.7 517.6 573.6 673.2 820.6

Less : Interest & Other Expenses Capitalized

-109.0 -172.2 -186.4 -230.5 -269.6 -282.6



Nov, 2013 Page | 59

Depreciation 133.8 143.8 155.8 167.2 180.7 249.6 Other Debits (incl. Prov for Bad debts) 0.0 0.0 0.0 0.0 0.0 0.0

Return on Equity on Wheeling Business

41.8 52.4 60.6 66.0 71.8 92.1

Public Interaction Program 0.0 0.0 0.0 0.0 0.0 0.0 Non Tariff Income (excluding wheeling charges received from other states)

0.0 0.0 0.0 0.0 0.0 0.0

Wheeling charges received from other states

0.0 0.0 0.0 0.0 0.0 0.0

Addition items (Prior period / true up, etc)

0.0 400.7 0.0 0.0 0.0 0.0

ARR Requirement 1426.5 2010.6 1744.9 1868.9 2050.4 2401.7

Table 62: Retail Supply ARR for 3rd Control Period (Rs. Crs)

Retail supply ARR FY 14 FY 15 FY 16 FY 17 FY 18 FY 19


Power Purchase Expenses 2406.9 2805.7 3215.5 3522.9 3909.8 4483.4

Transmission Charges 266.8 372.9 424.5 476.9 558.5 670.2

Employee Expenses 408.3 439.4 473.1 509.7 549.2 592.2

R&M Expenses 4.1 5.2 5.3 5.9 6.5 8.9

A&G Expenses 19.7 21.6 23.7 26.1 28.6 31.5 Interest & Financing Charges (other than interest on working capital)

0.0 0.0 0.0 0.0 0.0 0.0

Less : Interest & Other Expenses Capitalized

0.0 0.0 0.0 0.0 0.0 0.0


Depreciation 0.0 0.0 0.0 0.0 0.0 0.0

Other Debits (incl. Prov for Bad debts) 3.0 3.2 3.6 3.8 4.1 4.4

Return on Equity on Wheeling Business

0.0 0.0 0.0 0.0 0.0 0.0

Public Interaction Program 0.2 0.6 0.6 0.7 0.8 0.9 Non Tariff Income (excluding wheeling charges received from other states)

303.8 285.6 306.1 326.4 349.0 374.6

Wheeling charges received from other states

0.0 0.0 0.0 0.0 0.0 0.0

Addition items (Prior period / true up, etc)

0.0 400.7 0.0 0.0 0.0 0.0

ARR Requirement 2877.9 3843.4 3931.1 4316.5 4812.6 5531.6

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