UJVNL Business Plan

Business Plan of UJVN Limited for Control Period

Business Plan for the Control Period (April 1, 2013 to March 31, 2016)

BEFORE THE

HON’BLE UTTARAKHAND ELECTRICITY REGULATORY COMMISSION DEHRADUN, UTTARAKHAND

UJVN Limited

Business Plan of UJVN Limited for Control Period

TABLE OF CONTENTS

1 INTRODUCTION ...... 16

1.1 COMPANY OVERVIEW ...... 17

1.2 VISION AND MISSION ...... 19

1.3 EXISTING INSTALLED CAPACITY ...... 20

1.4 UPCOMING GENERATION CAPACITY: ...... 23

2 CAPITAL EXPENDITURE PLAN – UPCOMING PROJECTS ...... 31

2.1 VYASI HYDROELECTRIC PROJECT (120 MW) ...... 32

2.2 LAKHWAR MULTIPURPOSE PROJECT (300 MW) ...... 38

2.3 KISHAU MULTIPURPOSE PROJECT (660 MW) ...... 44

2.4 SIRKARI BHYOL RUPSIABAGAR HYDROELECTRIC PROJECT (210 MW) ...... 49

2.5 BOWALA NAND PRAYAG HYDROELECTRIC PROJECT (300 MW) ...... 53

2.6 NAND PRAYAG LANGASU HYDROELECTRIC PROJECT (100 MW) ...... 58

2.7 TAMAK LATA HYDROELECTRIC PROJECT (250 MW)...... 63

2.8 PALA MANERI HYDROELECTRIC PROJECT (480 MW) ...... 67

2.9 BHAIRONGHATI HYDROELECTRIC PROJECT (381 MW) ...... 68

3 CAPITAL EXPENDITURE PLAN – EXISTING PROJECTS ...... 69

3.1 CHIBRO POWER STATION (240 MW) ...... 70

3.2 KHODRI POWER STATION (120 MW) ...... 76

3.3 DHAKRANI POWER STATION (33.75 MW) ...... 82

3.4 DHALIPUR POWER STATION (51 MW) ...... 88

3.5 KULHAL POWER STATION (30 MW) ...... 94

3.6 TILOTH POWER STATION (90 MW) ...... 100

3.7 CHILLA POWER STATION (144 MW) ...... 106

3.8 KHATIMA POWER STATION (41.40 MW) ...... 112

3.9 RAMGANGA POWER STATION (198 MW) ...... 118

3.10 MANERI BHALI - II HYDROELECTRIC PROJECT (304 MW) ...... 124

3.11 REFURBISHMENT OF ASAN BARRAGE, AT DHALIPUR (DEHRADUN) ...... 128

3.12 REFURBISHING OF ICHARI DAM, AT ICHARI, KOTI (DEHRADUN) ...... 130

3.13 REHABILITATION WORK OF VIRBHADRA BARRAGE, PASHULOK, RISHIKESH ...... 132

3.14 REFURBISHMENT OF DAKPATHAR BARRAGE, AT DAKPATHAR (DEHRADUN) ...... 134

3.15 REFURBISHMENT OF MANERI DAM AT MANERI, UTTRAKASHI ...... 136

Business Plan of UJVN Limited for Control Period

3.16 SPECIAL CLOSURE WORKS OF CIVIL & HYDRO MECHANICAL STRUCTURES FOR YAMUNA HYDEL SCHEME STAGE–I

(PART-I&II) & STAGE-IV ...... 138

3.17 CLOSURE OF CHILLA HEP FOR SPECIAL REPAIR OF POWER CHANNEL, SUBMERGED PARTS OF STRUCTURES & HYDRO-

MECHANICAL COMPONENTS OF VIRBHADRA BARRAGE, PASHULOK, RISHIKESH ...... 140

4 MAJOR SHUTDOWN PLAN OF POWER STATIONS...... 143

4.1 MAJOR SHUTDOWN PLAN OF POWER STATIONS ...... 144

5 SUMMARY ...... 146

5.1 CAPITAL EXPENDITURE & CAPITALIZATION...... 147

6 TECHNICAL REPORT OF EXISTING POWER STATIONS ...... 149

6.1 OBJECTIVE OF THE TECHNICAL REPORT ...... 150

6.2 TECHNICAL REPORT OF TILOTH POWER STATION ...... 151

6.3 TECHNICAL REPORT OF CHIBRO POWER STATION ...... 166

6.4 TECHNICAL REPORT OF DHAKRANI POWER STATION ...... 179

6.5 TECHNICAL REPORT OF DHALIPUR POWER STATION ...... 192

6.6 TECHNICAL REPORT OF KHODRI POWER STATION ...... 205

6.7 TECHNICAL REPORT OF KULHAL POWER STATION ...... 218

6.8 TECHNICAL REPORT OF CHILLA POWER STATION ...... 231

6.9 TECHNICAL REPORT OF KHATIMA POWER STATION ...... 244

6.10 TECHNICAL REPORT OF RAMGANGA POWER STATION ...... 256

6.11 TECHNICAL REPORT OF MANERI BHALI – II HYDROELECTRIC PROJECT ...... 271

7 ANNEXURES ...... 278

7.1 ANNEXURE 1: 10 DAILY DISCHARGE TILOTH POWER STATION...... 279

7.2 ANNEXURE 2: 10 DAILY DISCHARGE CHIBRO POWER STATION ...... 280

7.3 ANNEXURE 3: 10 DAILY DISCHARGE DHAKRANI POWER STATION ...... 281

7.4 ANNEXURE 4: 10 DAILY DISCHARGE DHALIPUR POWER STATION ...... 282

7.5 ANNEXURE 5: 10 DAILY DISCHARGE KHODRIPOWER STATION ...... 283

7.6 ANNEXURE 6: 10 DAILY DISCHARGE KULHAL POWER STATION ...... 284

7.7 ANNEXURE 7: 10 DAILY DISCHARGE CHILLA POWER STATION ...... 285

7.8 ANNEXURE 8: 10 DAILY DISCHARGE KHATIMA POWER STATION ...... 286

7.9 ANNEXURE 9: 10 DAILY DISCHARGE MANERI BHALI – II HYDROELECTRIC PROJECT ...... 287

7.10 ANNEXURE 10: BREAKUP OF COST FOR BALANCE WORKS AS PER ORIGINAL DPR AS APPROVED BY CEA AND PROPOSED

NEW WORKS FOR MANERI BHALI –II HEP...... 288

7.11 ANNEXURE 11: NATURE OF ENVIRONMENTAL IMPACTS CAUSED BY RMU AND SUGGESTED MITIGATION MEASURES 302

Business Plan of UJVN Limited for Control Period

7.12 ANNEXURE 12: FINANCING OF RMU OF SIX HYDRO ELECTRIC PROJECTS THROUGH KFW ...... 307

ANNEXURE 13: LETTER OF CEA FOR LAKHWAR POWER STATION ...... 314

7.13 ANNEXURE 14: LOAN AGREEMENT OF PFC FOR RMU OF KHATIMA POWER STATION ...... 315

7.14 Annexure 15: Note on Small Hydroelectric Projects...... 3156

7.15 Annexure 16 : Note on Manpower Planning of UJVN Ltd. during the Control Period...... 317

Business Plan of UJVN Limited for Control Period

List of Tables

Table 1: Brief History of Formation of UJVN Limited ...... 19

Table 2: Salient Features of the Existing Power Stations ...... 20

Table 3: Generation of Hydro Projects in UJVN Limited for last 5 years ...... 22

Table 4: Planned Capacity Addition by UJVN Limited ...... 24

Table 5: Capital Expenditure during Control Period – Vyasi Project ...... 33

Table 6: Capital Cost – Vyasi Project ...... 34

Table 7: Funding Pattern during the Control Period – Vyasi Project ...... 36

Table 8: Capex & Capitalization during the Control Period – Vyasi Project ...... 37

Table 9: Capital Expenditure during the Control Period – Lakhwar Project ...... 39

Table 10: Capital Cost – Lakhwar Project ...... 40

Table 11: Funding Pattern during the Control Period – Lakhwar Project ...... 43

Table 12: Capex & Capitalization during the Control Period – Lakhwar Project ...... 43

Table 13: Capital Expenditure during the Control Period – Kishau Project ...... 45

Table 14: Capital Cost – Kishau Project ...... 46

Table 15: Funding Pattern during the Control Period – Kishau Project ...... 48

Table 16: Capex & Capitalization during the Control Period – Kishau Project ...... 48

Table 17: Capital Expenditure during the Control Period – Sirkari Bhyol Rupsiabagar Project ...... 49

Table 18: Capital Cost – Sirkari Bhyol Rupsiabagar Project ...... 50

Table 19: Funding Pattern during the Control Period – Sirkari Bhyol Rupsiabagar Project .... 52

Table 20: Capex & Capitalization during the Control Period –Sirkari Bhyol Rupsiabagar Project ...... 52

Table 21: Capital Expenditure during the Control Period – Bowala Nand Prayag Project ...... 53

Table 22: Capital Cost – Bowala Nand Prayag Project ...... 54

Table 23: Funding Pattern during the Control Period – Bowla Nand Prayag Project ...... 57

Business Plan of UJVN Limited for Control Period

Table 24: Capex & Capitalization during the Control Period – Bowla Nand Prayag Project ... 57

Table 25: Capital Expenditure during the Control Period – Nand Prayag Langasu Project ..... 58

Table 26: Capital Cost – Nand Prayag Langasu Project ...... 59

Table 27: Funding Pattern during the Control Period – Nand Prayag Langasu Project ...... 61

Table 28: Capex & Capitalization during the Control Period – Nand Prayag Langasu Project 62

Table 29: Capital Expenditure during the Control Period – Tamak Lata Project ...... 63

Table 30: Capital Cost – Tamak Lata Project ...... 64

Table 31: Funding Pattern during the Control Period – Tamak Lata Project ...... 66

Table 32: Capex & Capitalization during the Control Period – Tamak Lata Project ...... 66

Table 33: Capital Expenditure during the Control Period – Chibro Project ...... 70

Table 34: Capital Cost – Chibro Project ...... 72

Table 35: Funding Pattern during the Control Period – Chibro Project ...... 75

Table 36: Capex & Capitalization during the Control Period – Chibro Project ...... 75

Table 37: Capital Expenditure during Control Period – Khodri Project ...... 76

Table 38: Capital Cost – Khodri Project ...... 78

Table 39: Funding Pattern during the Control Period – Khodri Project ...... 81

Table 40: Capex & Capitalization during the Control Period – Khodri Project ...... 81

Table 41: Capital Expenditure during the Control Period – Dhakrani Project ...... 82

Table 42: Capital Cost – Dhakrani Project...... 84

Table 43: Funding Pattern during the Control Period – Dhakrani Project...... 87

Table 44: Capex & Capitalization during the Control Period – Dhakrani Project ...... 87

Table 45: Capital Expenditure during the Control Period – Dhalipur Project ...... 88

Table 46: Capital Cost – Dhalipur Project ...... 90

Table 47: Funding Pattern during Control Period – Dhalipur Project ...... 93

Table 48: Capex & Capitalization during the Control Period – Dhalipur Project ...... 93

Table 49: Capital Expenditure during the Control Period – Kulhal Project ...... 94

Business Plan of UJVN Limited for Control Period

Table 50: Capital Cost – Kulhal Project ...... 96

Table 51: Funding Pattern during the Control Period – Kulhal Project ...... 99

Table 52: Capex & Capitalization during the Control Period – Kulhal Project ...... 99

Table 53: Capital Expenditure during the Control Period – Tiloth Project ...... 101

Table 54: Capital Cost – Tiloth Project ...... 102

Table 55: Funding Pattern during the Control Period – Tiloth Project ...... 105

Table 56: Capex & Capitalization during the Control Period – Tiloth Project ...... 105

Table 57: Capital Expenditure during the Control Period – Chilla Project ...... 106

Table 58: Capital Cost – Chilla Project ...... 108

Table 59: Funding Pattern during the Control Period – Chilla Project ...... 111

Table 60: Capex & Capitalization during the Control Period – Chilla Project ...... 111

Table 61: Capital Expenditure during the Control Period – Khatima Project ...... 112

Table 62: Capital Cost – Khatima Project ...... 114

Table 63: Funding Pattern during the Control Period – Khatima Project ...... 117

Table 64: Capex & Capitalization during the Control Period – Khatima Project ...... 117

Table 65: Capital Expenditure during the Control Period – Ramganga Project ...... 119

Table 66: Capital Cost – Ramganga Project ...... 120

Table 67: Funding Pattern during the Control Period – Ramganga Project ...... 122

Table 68: Capex & Capitalization during the Control Period – Ramganga Project ...... 123

Table 69: Capital Expenditure during the Control Period – Maneri Bhali - II Project ...... 125

Table 70: Capital Cost – Maneri Bhali - II Project ...... 126

Table 71: Funding Pattern during the Control Period – Maneri Bhali - II Project ...... 127

Table 72: Capex & Capitalization during the Control Period – Maneri Bhali - II Project ...... 127

Table 73 : Summary of expenses proposed under DRIP Scheme and Closure Works (in Rs. Lakh) ...... 141

Table 74 : Outage Plan during the Control Period for UJVN Limited...... 145

Business Plan of UJVN Limited for Control Period

Table 75: Capex & Capitalization during the control period - UJVN Limited ...... 147

Table 76: Debt & Equity for Capital Expenditure during the control period - UJVN Limited 148

Table 77: 90% dependable year – Tiloth Power Station ...... 152

Table 78: Discharge & Generation Data – Tiloth Power Station ...... 154

Table 79: Design Energy: Tiloth Power Station ...... 155

Table 80: Uncontrollable Losses – Tiloth Power Station ...... 155

Table 81: Year wise Maximum Possible Generation (MU) – Tiloth Power Station ...... 157

Table 82: Design Energy – Tiloth Power Station ...... 157

Table 83: Plant Availability during FY 2000 - 12 – Tiloth Power Station...... 158

Table 84: % Generation Loss on account of various Factors – Tiloth Power Station ...... 160

Table 85: Auxiliary and Transformation Losses – Tiloth Power Station ...... 161

Table 86: 90% Dependable year – Chibro Power Station ...... 167

Table 87: Discharge & Generation Data – Chibro Power Station ...... 169

Table 88: Design Energy- Chibro Power Station ...... 170

Table 89: Uncontrollable Losses – Chibro Power Station ...... 170

Table 90: Year wise Maximum Possible Generation (MU) – Chibro Power Station ...... 171

Table 91: Design Energy – Chibro Power Station ...... 172

Table 92: Plant Availability during FY 2000 - 12 – Chibro Power Station ...... 172

Table 93: % Generation Loss on account of various Factors – Chibro Power Station ...... 174

Table 94: Auxiliary and Transformation Losses – Chibro Power Station ...... 174

Table 95: 90% Dependable Year– Dhakrani Power Station ...... 180

Table 96: Discharge & Generation Data – Dhakrani Power Station ...... 182

Table 97- Design Energy: Dhakrani Power Station ...... 183

Table 98: Uncontrollable Losses – Dhakrani Power Station ...... 183

Table 99: Year wise Maximum Possible Generation (MU) – Dhakrani Power Station ...... 184

Table 100: Design Energy – Dhakrani Power Station ...... 185

Business Plan of UJVN Limited for Control Period

Table 101: Plant Availability during FY 2000 - 12 – Dhakrani Power Station ...... 185

Table 102: % Generation Loss on account of various Factors – Dhakrani Power Station ..... 187

Table 103: Auxiliary and Transformation Losses – Dhakrani Power Station ...... 188

Table 104: 90% Dependable year – Dhalipur Power Station ...... 193

Table 105: Discharge & Generation Data – Dhalipur Power Station ...... 195

Table 106: Design Energy- Dhalipur Power Station ...... 196

Table 107: Uncontrollable Losses – Dhalipur Power Station ...... 196

Table 108: Year wise Maximum Possible Generation (MU) – Dhalipur Power Station ...... 197

Table 109: Design Energy – Dhalipur Power Station ...... 198

Table 110: Plant Availability during FY 2001- 12 – Dhalipur Power Station ...... 198

Table 111: % Generation Loss on account of various Factors – Dhalipur Power Station ...... 200

Table 112: Auxiliary and Transformation Losses – Dhalipur Power Station ...... 201

Table 113: 90% Dependable year – Khodri Power Station ...... 207

Table 114: Discharge & Generation Data – Power Station ...... 208

Table 115: Design Energy-Khodri Power Station ...... 209

Table 116: Uncontrollable Losses – Khodri Power Station ...... 209

Table 117: Year wise Maximum Possible Generation (MU) – Khodri Power Station ...... 210

Table 118: Design Energy – Khodri Power Station ...... 211

Table 119: Plant Availability during FY 2000 - 12 – Khodri Power Station ...... 211

Table 120: % Generation Loss on account of various Factors – Khodri Power Station ...... 213

Table 121: Auxiliary and Transformation Losses – Khodri Power Station ...... 214

Table 122: 90% dependable year – Kulhal Power Station ...... 219

Table 123: Discharge & Generation Data – Kulhal Power Station ...... 221

Table 124: Design Energy-Kulhal Power Station ...... 222

Table 125: Uncontrollable Losses – Kulhal Power Station ...... 222

Table 126: Year wise Maximum Possible Generation (MU) – Kulhal Power Station ...... 223

Business Plan of UJVN Limited for Control Period

Table 127: Design Energy – Kulhal Power Station ...... 224

Table 128: Plant Availability during FY 2001- 12 – Kulhal Power Station ...... 224

Table 129: % Generation Loss on account of various Factors – Kulhal Power Station ...... 225

Table 130: Auxiliary and Transformation Losses – Kulhal Power Station ...... 226

Table 131: 90% dependable year – Chilla Power Station ...... 232

Table 132: Discharge & Generation Data – Chilla Power Station ...... 234

Table 133: Design Energy: Chilla Power Station ...... 235

Table 134: Uncontrollable Losses – Chilla Power Station ...... 235

Table 135: Year wise Maximum Possible Generation (MU) – Chilla Power Station ...... 236

Table 136: Design Energy – Chilla Power Station ...... 237

Table 137: Plant Availability during FY 2002- 12 – Chilla Power Station ...... 237

Table 138: % Generation Loss on account of various Factors – Chilla Power Station ...... 239

Table 139: Auxiliary and Transformation Losses – Chilla Power Station ...... 240

Table 140: 90% dependable year – Khatima Power Station ...... 246

Table 141: Discharge & Generation Data – Khatima Power Station ...... 247

Table 142: Design Energy- Khatima Power Station ...... 248

Table 143: Uncontrollable Losses – Khatima Power Station ...... 248

Table 144: Year wise Maximum Possible Generation (MU) – Khatima Power Station ...... 249

Table 145: Design Energy – Khatima Power Station ...... 250

Table 146: Plant Availability during FY 2000 - 12 – Khatima Power Station ...... 250

Table 147: % Generation Loss on account of various Factors – Khatima Power Station ...... 251

Table 148: Auxiliary and Transformation Losses – Khatima Power Station ...... 252

Table 149: Annual Discharge ...... 260

Table 150: 90% Dependable year ...... 261

Table 151: Energy Generation potential for the dependable year on 10 daily discharge basis ...... 262

Business Plan of UJVN Limited for Control Period

Table 152: Plant availability based on Peaking Capability ...... 265

Table 153: Plant Availability during 2007-12 ...... 266

Table 154: Auxiliary and Transformation losses ...... 267

Table 155: Plant Availability during FY 2008-12 – Maneri Bhali - II Hydroelectric Project.... 272

Table 156: % Generation Loss on account of various Factors – Maneri Bhali - II Hydroelectric Project ...... 274

Table 157: Auxiliary and Transformation Losses – Maneri Bhali - II Hydroelectric Project .. 275

Business Plan of UJVN Limited for Control Period

BEFORE THE HON’BLE UTTARAKHAND ELECTRICITY REGULATORY COMMISSION DEHRADUN, UTTARAKHAND

IN THE MATTER OF:

The Business Plan of UJVN Limited for FY 2013-14 to FY 2015-2016 under Section 62 and 86 of the Electricity Act, 2003 read with the relevant regulations and guidelines of the Hon’ble Commission.

And

IN THE MATTER OF THE APPLICANT:

UJVN Limited, a Company incorporated under the provisions of the Companies Act, 1956 and having its registered office at UJJWAL, Maharani Bagh, GMS Road, Dehradun – Petitioner

Business Plan of UJVN Limited for Control Period

A. Specific Legal Provisions under which the Petition is being filed

The Hon’ble Commission has notified the Uttarakhand Electricity Regulatory Commission (Terms and Conditions for Determination of Tariff) Regulations, 2011, on 19th December 2011. In accordance with Regulation 9 of these regulations states that Applicant is to submit a Business Plan for the entire control period. Regulation 9(1) states:

“An Applicant shall submit, under affidavit and as per the UERC (Conduct of Business) Regulations, 2004, a Business Plan by May 31, 2012, for the Control Period of three (3) financial years from April 1, 2013 to March 31, 2016,

a) The Business Plan for the Generating Company shall be for the entire control period and shall, interalia, contain-

(i) Capital investment plan, which shall include details of the investments planned by the Generating Company for existing stations, yearly phasing of capital expenditure along with the source of funding, financing plan and corresponding capitalisation schedule. This plan shall be commensurate with R&M schemes and proposed efficiency improvements for various plants of the company.

(ii) The capital investment plan shall show separately, on-going projects that will spill over into the years under review, and new projects (along with justification) that will commence in the years under review but may be completed within or beyond the tariff period.

(iii) The Generating Company shall submit plant-wise details of the capital structure and cost of financing (interest on debt and return on equity), after considering the existing market conditions, terms of the existing loan agreements, risks associated in generation business and creditworthiness;

(iv) Details related to major shut down of machines, if any

Business Plan of UJVN Limited for Control Period

(v) Trajectory of performance parameters”

In compliance with this Regulation, the Business Plan of UJVN Limited has been submitted through this petition.

B. Facts of the Case

1. The Petitioner, UJVN Limited, is a company incorporated under the provisions of the Companies Act, 1956, having its registered office at UJJWAL, Maharani Bagh, GMS Road, Dehradun.

2. It is submitted that Government of India (GoI) vide order dated November 5, 2001 transferred all hydropower assets of Uttar Pradesh Jal Vidyut Nigam Limited (UPJVNL) located in the State of Uttarakhand to UJVN Limited with effect from November 09, 2001. In compliance to the said order, administrative and financial control of all hydro Power Stations of UPJVNL in operation or under construction in the State of Uttarakhand was taken over by UJVN Limited with effect from November 09, 2001. GOI order also defines the basis of division of assets and liabilities between UPJVNL and UJVN Limited.

3. Though administrative and financial control was transferred to UJVN Limited on November 09, 2001, UJVN Limited initiated discussions with UPJVNL for formulation of transfer scheme as per the said GOI order on mutually agreed terms.

4. Government of Uttarakhand (GoU) has notified the provisional transfer scheme vide its notification no. 70/AS (E)/I/2008-04 (3)/22/08 dated 07/03/08.

C. Prayer to Hon’ble Commission

Further, UJVN Limited prays the following before the Hon’ble Commission:

1) Approve the Business Plan for UJVN Limited for the Control Period (FY 2013- 14 to FY 2015-16) in accordance with Regulation 9 of Uttarakhand Electricity

Business Plan of UJVN Limited for Control Period

Regulatory Commission (Terms and Conditions for Determination of Tariff) Regulations, 2011.

2) Approve planned outages of Power Stations and also grant permission for change in the schedule.

3) Approve Methodology adopted for calculation of NAPAF and other technical parameters.

4) Condone any inadvertent omission/ errors/ shortcomings and permit UJVN Limited to add/ change/ modify/ alter this filing and make further submissions as may be required at a future date.

5) Any other relief that the Hon’ble Commission may deem fit.

Business Plan of UJVN Limited for Control Period

1 INTRODUCTION

Business Plan of UJVN Limited for Control Period

1.1 Company Overview

1.1.1 UJVN Limited is a wholly owned Corporation of the Government of Uttarakhand. The main objects to be pursued by the company are as under:

To establish takeover, operate and maintain power generating stations harnessing the conventional, non-conventional, nuclear and other sources of energy by what so ever name called that include sub-stations, transmission lines, other ancillaries and activities that are essential for generation, transmission, distribution and trading of power. To carry on its activities within the State of Uttarakhand or elsewhere as may be found feasible. To make arrangements with any Company, Authority, Government or other persons or institutions for the operation and maintenance of any generating station owned by it (including transmission lines and other works connected therewith) on such terms and conditions as may be agreed upon between it and the Company. To take such measures as in the opinion of the Company, are calculated to advance the development of water power in the State of Uttarakhand and may carry out power and Hydro –metric survey work and cause to be made such maps, plans, sections and estimate as are necessary for any of the said purpose. To carry out investigation and to prepare one or more schemes relating to the establishment or acquisition of generating stations, tie-lines, sub-stations and transmission lines for promoting the use of electricity within the State of Uttarakhand. To operate and maintain in the most efficient and economical manner the generating stations, tie-lines, sub-stations and main transmission lines, owned by the Company. To enter into agreement with any licensee licensed under the Indian Electricity Act, 1910 or any other Act, Law of Regulation in force for the time being, or as

Business Plan of UJVN Limited for Control Period

modified from time to time or with any person for use of any transmission line, distribution line or main transmission line of that licensee or person for such time and upon such terms as may be agreed. To enter into arrangement on such terms as may be agreed upon, for the sale of electricity generated by it to the State Electricity Company constituted for Uttarakhand or for the sale of electricity generated by it to any other state, body, person by itself with the consent of such person or persons duly authorized or licensed under prevalent Laws and Regulations or on its own account. To avail such rights, exercise such powers and functions and to perform such duties as are conferred upon or expected of the company under the provisions of such Laws, legislation and regulations as are in force from time to time. To do such other acts and things as are authorized to be done under the Electricity (Supply) Act, 1948, or any other Act, Laws or regulations in force or amended from time to time. To do such other acts and things as are authorized to be done under Indian Electricity Act, 1910, as amended from time to time.

1.1.2 The erstwhile Uttar Pradesh State Electricity Board was trifurcated pursuant to enactment of U.P. Electricity Reforms Act, 1999. U.P. State Electricity Reforms Transfer Scheme, 2000 was promulgated for execution of the trifurcation of erstwhile UPSEB into U.P. Power Corporation Ltd. (In short UPPCL), U.P. Jal Vidyut Nigam Ltd. (In short UPJVNL) and U.P. Rajya Vidyut Utpadan Nigam Limited (UPRVUNL). By operation of the aforesaid Scheme all the Hydro Electric Projects earlier owned and operated by UPSEB were transferred to UPJVNL (a Govt. Company existing prior to the said trifurcation) in addition to other projects owned and operated by the UPJVNL previously.

1.1.3 Uttar Pradesh was bifurcated by enforcement of U.P. Reorganization Act, 2000 as a result thereof the State of Uttarakhand came into existence. The Government of

Business Plan of UJVN Limited for Control Period

India issued an order dated 05-11-01 u/s 63(4)(a) of the Reorganization Act whereby assets and liabilities between UPJVNL and UJVN Limited were divided. By operation of this order all the Hydro Power Assets of UPJVNL located in the State of Uttarakhand were transferred to UJVN Limited. In compliance to the said order, administrative and financial control of all hydro power plants of UPJVNL in operation or under construction was taken over by UJVN Limited with effect from November 09, 2001.

1.1.4 The brief history of formation of UJVN Limited is presented in Table 1.

Table 1: Brief History of Formation of UJVN Limited Milestone Date UPSEB Unbundled under UPSEB Transfer Scheme 14-01-2000 Uttarakhand State Created under UP Reorganisation Act 09-11-2000 UJVN Limited formed under Companies Act, 1956 12-02-2001 UJVN Limited Commenced Operations 09-11-2001 UJVN Limited Took Possession of Assets 09-11-2001

1.1.5 Presently, UJVN Limited operates Hydro Power Stations ranging in capacity from 0.2 MW to 304 MW, totaling around 1310.25 MW. Though the State was more or less sufficient in energy generation to meet its own requirements at the time of its formation, it is falling short of power at present. As such efficient operation of exiting hydro power projects for economic well-being and growth of the State and its people has become relevant and essential.

1.2 Vision and Mission

1.2.1 The vision of UJVN Limited is to be a significant player in the National Power Sector and best corporate in Uttarakhand. It aims to be an excellent & efficient organization

Business Plan of UJVN Limited for Control Period

on the strength of its human resources and induce adjacent infrastructure business that provides opportunities for growth.

1.2.2 The Mission of the Nigam is to contribute to improvement in the quality of life in Uttarakhand. To achieve this, UJVN Limited has adopted a value based approach and its values include:

Creation of value for all stakeholder

Result oriented with professional work culture

Earn trust through fair business practices with all

Growth balanced with environmental protection & enrichment

Law abiding

1.3 Existing Installed Capacity

1.3.1 Currently, UJVN Limited has an installed capacity of 1310.25 MW with installed capacity of Power Stations ranging from 0.2 MW to 304 MW. The salient features of these existing Power Stations are summarized in Table 2.

Table 2: Salient Features of the Existing Power Stations S. Power Installed Year of Type River Design Design N Station Capacity Commiss of Head Discharge (MW) ioning Scheme (m) (m3/s) 1 MB-II 304.00 2008 ROR Bhagirathi 247.60 142.00 2 Khodri 120.00 1984 ROR Tons 57.90 200.00 3 Tiloth 90.00 1984 ROR Bhagirathi 147.50 71.40 4 Chilla 144.00 1980 ROR Ganga 32.50 565.00 5 Chibro 240.00 1975 ROR Tons 110 200.00 6 Kulhal 30.00 1975 ROR Yamuna 18.00 198.00 7 Ramganga 198.00 1975 Reservoir Ramganga 84.40 235.60

Business Plan of UJVN Limited for Control Period

S. Power Installed Year of Type River Design Design N Station Capacity Commiss of Head Discharge (MW) ioning Scheme (m) (m3/s) 8 Dhakrani 33.75 1965 ROR Yamuna 19.80 199.20 9 Dhalipur 51.00 1965 ROR Yamuna 30.48 199.20 10 Khatima 41.40 1956 ROR Sharda 17.98 269.00 11 Pathri 20.40 1955 ROR Ganga 9.75 253.00 12 M. Pur 9.30 1952 ROR Ganga 5.70 255.00 13 Galogi 3.00 1907 ROR Bhatta 285.00 1.36 14 Urgam 3.00 1998 ROR Kalpganga 196.00 1.86 15 Tharali 0.40 1989 ROR Pranmati 79.77 0.67 16 Badrinath–II 1.25 2004 ROR Rishiganga 75.45 2.07 17 Pandukesh 0.75 2004 ROR Laxman 113.00 0.94 war ganga 18 Jumma 1.20 2005 ROR Jumma 143.50 1.07 gad 19 Tapovan 0.80 2005 ROR Dak 274.00 0.41 Gadera 20 Sonprayag 0.50 2002 ROR Sone 46.70 1.36 21 Sapteshwar 0.30 1994 ROR Koiralgad 82.30 0.48 22 Kanchauti 2.00 1993 ROR Kanchauti 400.00 0.62 gad 23 Chhirkila 1.50 1997 ROR Dukugad 275.00 0.68 24 Relagad 3.00 2004 ROR Relagad 264.83 1.42 25 Kulagad 1.20 1995 ROR Kulagad 200.00 0.79 26 Pilangad 2.25 2004 ROR Pilangad 102.00 2.75 27 Harsil 0.20 2000 ROR Bhagirathi 114.00 0.26 28 Kaliganga 4.00 2012 ROR Kaliganga 166.00 3.00 29 Suringad 0.80 1986 ROR Sureingad 151.00 0.76

Business Plan of UJVN Limited for Control Period

S. Power Installed Year of Type River Design Design N Station Capacity Commiss of Head Discharge (MW) ioning Scheme (m) (m3/s) 30 Taleshwar 0.60 2000 ROR Kaliganga 189.00 0.59 31 Barar 0.75 1997 ROR Ramganga 99.48 0.96 32 Chharandeo 0.40 2000 ROR Kaliganga 229.74 0.19 33 Garaon 0.30 2001 ROR Ramganga 119.50 0.24 34 Kotabagh 0.20 1990 ROR Dabaka 29.33 0.94 Total 1310.25

1.3.2 Most of the Power Stations were commissioned by the early 1980’s and the oldest Galogi Power Station was commissioned way back in 1907. The latest hydro station to be commissioned is Kaliganga-I SHP with an installed capacity of 4 MW in the year 2012. Thus, it can be said that about more than 3 quarters of the capacity has been in operation for nearly 30 to 60 years and is, almost at the end of the life.

1.3.3 All the UJVN Limited Power Stations except Ramganga are run of the river stations and thus are highly dependent on water availability and monsoon for electricity generation. Table 3 summarizes generation of hydro projects in the last 5 years.

Table 3: Generation of Hydro Projects in UJVN Limited for last 5 years Year Unit 2007-08 2008-09 2009-10 2010-11 2011-12

Chibro Gen. (MU) 755.08 837.68 587.89 795.69 848.97

Khodri Gen. (MU) 354.66 379.98 275.89 361.77 382.87

Dhakrani Gen. (MU) 148.93 146.53 105.09 143.02 152.76

Dhalipur Gen. (MU) 210.70 224.44 160.15 210.84 229.58

Kulhal Gen. (MU) 149.76 143.68 112.62 142.53 157.83

Business Plan of UJVN Limited for Control Period

Year Unit 2007-08 2008-09 2009-10 2010-11 2011-12

Tiloth Gen. (MU) 466.14 403.80 449.08 504.41 516.11

MB-II Gen. (MU) 77.02 1044.95 1198.04 1335.96 1351.15

Chilla Gen. (MU) 825.97 776.59 739.49 775.15 910.09

Ramganga Gen. (MU) 279.06 325.48 174.29 325.62 416.42

Khatima Gen. (MU) 155.43 140.65 151.01 155.94 164.00

LHPs Gen. (MU) 3422.75 4423.78 3953.55 4750.93 5129.78

SHPS Gen. (MU) 180.43 189.45 173.00 155.34 132.03

Total Gen. (MU) 3603.18 4613.23 4126.54 4906.26 5261.82

1.3.4 Three Power Stations, namely, MB-II, Chilla and Chibro account for nearly 60% of the generation but Chilla & Chibro are now more than 30 years old. The generation of UJVN Limited increased by 28% between FY 2007-08 and FY 2008-09 on account of commissioning of MB-II, in FY 2007-08. There was a dip in generation between FY 2008-09 and FY 2009-10 due to low hydrology.

1.4 Upcoming Generation Capacity:

1.4.1 UJVN Limited plans to expand its current capacity base and has about 3276 MW of Generating Plants in different stages of planning and implementation. The details of the projects planned and currently being implemented by UJVN Limited in the coming years are presented in the Table 4 below.

Business Plan of UJVN Limited for Control Period

Table 4: Planned Capacity Addition by UJVN Limited S.No. Name of Estimated District River/ Expected Project Potential Tributary Commissioning (MW) Year

1 Vyasi 120 Dehradun Yamuna 2016

2 Lakhwar 300 Dehradun Yamuna 2018

3 Bowla 300 Chamoli Alaknanda 2019 Nandprayag

4 Tamak lata 250 Chamoli Dhauliganga 2019

5 Nand Pyayag 100 Chamoli Alaknanda 2020 Langasu

6 Sirkari Bhyol 210 Pithoragarh Goriganga 2021 Rupsiabagar

7 Sela Urthing 230 Pithoragarh Dhauliganga 2023

8 Kishau 660 Dehradun Tons 2024

9 Pala Maneri 480 Uttarkashi Bhagirathi On hold

10 Bhairon Ghati 381 Uttarkashi Bhagirathi On hold

11 Taluka Sankri 140 Uttarkashi Tons 2026*

12 Rishiganga I 70 Chamoli Rishiganga 2026*

13 Rishiganga – II 35 Chamoli Rishiganga 2026*

Total 3276

*Subject to clearance of Wildlife Board and MoEF.

1.4.2 It will be important to consider some of these Projects in this business plan as some capital expenditure related to these projects shall also be done during the current

Business Plan of UJVN Limited for Control Period

control period. Two hydro projects namely Pala Maneri and Bhairon Ghati on the Bhagirathi River are currently on hold due to environmental issues. Taluka Sankri, Rishiganga – I , Rishigana – II and Sela Urthing are still under planning phase and hence no capital expenditure will be incurred during the control period. Sela Urthing is expected to be commissioned in 2023 and no capital expenditure is expected to be incurred during the control period.

In addition to these Large Hydroelectric Projects, quite a number of Small Hydroelectric Projects are in operation as well as in various stages of implementation requiring substantial capital investments during the Control Period 2013-14 to 2015-16. These have been appended as Annexure-15.

Effort towards Diversification of Generation Base

1.4.3 Electricity demand in the state has grown exponentially due to rapid industrialization as a result of industry friendly policies and special package granted to the State by the Union Government. The demand for electricity has been growing at the rate of about 14% per annum during the last 8 years and the demand-supply gap is increasing. At present power generation in the state is wholly dependent on Hydro projects and allocation of power from central pool is not sufficient to meet the requirement of the State. The power deficit becomes acute during winter season as freezing temperatures causes low river discharges leading to lower generation whereas demand goes up significantly.

Bottlenecks in development of Hydro projects

1.4.4 The state could not harness the full potential of Hydro power due to various reasons, notably among them are the inordinate delay in various clearances for the upcoming hydro projects, suspension / closure of 480 MW Pala Maneri & 381 MW Bhairoghati projects of State PSU (UJVN Limited), 600 MW Lohari Nag Pala project of

Business Plan of UJVN Limited for Control Period

NTPC Ltd. by Govt. of India and cancellation of already issued environment clearance to some Hydroelectric projects. Because of these factors the development of hydro power projects in the state is not taking place at desired pace. It is pertinent to mention that due to various environmental, social and religious issues, the development of hydro power in Uttarakhand state has been greatly hampered. Several religious agitations against developments of hydro power projects have resulted in the closure of three aforesaid hydro projects in the state and there is a strong demand for closure of other up-coming projects.

Alternate Resources: Development of Gas based thermal power plant

1.4.5 For the reasons listed in the previous section, the State Government is exploring alternatives to hydro power. In this regard Gas Based Power Projects have been initiated by the State Government (UJVN Ltd, A Govt. Uttarakhand Undertaking) in joint venture with GAIL (India) Ltd. at Haridwar & Kashipur in Uttarakhand, but Government of India has informed that they do not have adequate Gas supply and have expressed its inability to allocate gas to the state for generation in near future.

Development of Coal based Power Plant and allocation of Coal Block

1.4.6 Uttarakhand state does not have any coal reserve and no coal block has been allocated to the state since its formation. Govt. of India has notified a new coal policy “The Auction by Competitive Bidding of Coal Mines Rules, 2012” on 02-02-2012. As per the information available on different websites, 54 Coal Blocks with total geological reserves of about 18.22 Billion Tonnes have been identified for allocation. Out of which 16 Blocks with 7.27 BT have been reserved for Government owned companies, 16 Coal Blocks with 8.16 BT for power sector companies selected through tariff based bidding and 22 Blocks with 7.29 BT for companies selected through auction have been earmarked for allocation. Allocation of above coal blocks will start soon.

Business Plan of UJVN Limited for Control Period

1.4.7 In this reference a meeting was held on 11th May 2012 under the Chairmanship of Secretary (Coal), GoI to finalize the terms and conditions for allocation of Coal Blocks to Government owned companies through auction by competitive bidding. Secretary (Coal), GoI has informed that coal blocks for Power Sector will be allotted only through competitive bidding.

Steps Taken For Allocation of Coal Block

1.4.8 Growing demand – supply gap of power is of utmost concern for the Government of Uttarakhand. To bridge the gap, a 2000 MW Coal Based Power Project is required.

1.4.9 In this context a request for allocation of coal block for 2000 MW Coal Based Power Project has been made by the Chief Minister of Uttarakhand vide his office letter No. 763/I(2)/2010-05/33/2007, dated 21.04.2010 to the Government of India.

1.4.10 In continuation to above Chief Secretary of Uttarakhand vide letter no. 760/I2/09/2012 dated 10th May, 2012 has further requested Secretary Coal, GoI for allocation of Coal Block for setting-up a 2000 MW thermal power plant at pit head on priority basis.

1.4.11 For development of Coal based Power Plant with Uttar Pradesh (UPPCL), Managing Director, UJVN Ltd. requested vide letter no. 1728/UJVNL/MD/Coal dated 26.04.2012 Chairman and Managing director, UPPCL for development of Thermal Power Plant under joint venture route. In this regard Nigam Official met and appraised the matter to CMD, UPPCL.. CMD, UPPCL has informed that there is no coal block left for link/tie-up for development of Coal based Thermal power plant.

1.4.12 In the Month of February 2012, Managing Director UJVN Ltd. discussed the power scenario of Uttarakhand with Chairman, Jharkhand Electricity Board (JSEB) and

Business Plan of UJVN Limited for Control Period

requested for development of a Coal based power plant at pit in Jharkhand. Chairman, JSEB vide letter no. 60/Ch. Dated 21-03-2012 invited UJVN Limited for setting up a coal based thermal power plant in Jharkhand and hydro power project in the territory of Uttarakhand through joint venture route for the mutual benefit of both states.

1.4.13 JSEB and UJVNL have decided to form a joint working group to go into details of the modality for formation of SPV/ Joint Venture as well as to develop a concept report on the proposed thermal and hydro power plant. The report of the working group shall be reviewed by JSEB/UJVNL and shall be put up to their respective Boards/ Government of the states for their approval.

1.4.14 UJVN Ltd. is also exploring other options for allocation of new Coal Blocks as per GoI Coal Block allotment policy. It is seeking consultancy services for “Identification, Application for Allocation and Bidding on behalf of UJVN Ltd. for coal block as per the final Terms & Conditions of the Ministry of Coal for allotment of Coal Blocks to Govt. Companies under Auction by Competitive Bidding of Coal Mines Rules 2012 for a 2000 MW Pit head coal based power project”. Various options (including case 2 PPP option) to establish the thermal plant will be explored and evaluated by UJVN Limited once the coal block is allocated to the state.

Initiative for increasing the Power availability for state of Uttarakhand

1.4.15 The Government of Uttaranchal has taken initiative to increase the base load power availability within the state. Consequent to persuasion by GoU the MoP, GoI has allocated a share of 200 MW in the Ultra Mega Power Project (UMPP) to be established in the state of Orissa. In this regard UJVNL has paid Rs. 35. 93 Crores to PFC towards its share of cost of land to be procured for the thermal plant. Once the UMPPP is awarded to the successful bidder this cost will be reimbursed by the selected bidder.

Business Plan of UJVN Limited for Control Period

Alternate Resources: Development of Solar Power Plants

1.4.16 The Renewable purchase obligation (RPO for solar) for Uttarakhand as stated in Uttarakhand Electricity Regulatory Commission (Renewable Purchase Obligation, its compliance & implementation of REC framework), Regulations 2010 is 0.025% for FY2010-11, FY2011-12 & FY2012-13 while for the control period i.e. FY2013-14, FY2014-15 & FY2015-16 the RPO would be 0.050%. For the compliance of this requirement UJVN limited has taken several initiatives.

1.4.17 Order for installation of 100 kWp Solar Photo Voltaic (SPV) Power Plant at Ujjwal, Dehradun has been placed with M/s Central Electronics Limited, a Public Sector Enterprise under DSIR of Ministry of Science & Technology, Government of India, on 23.12.2011. Total cost of installation of 100 kWp Solar Photo Voltaic (SPV) Power Plant at Ujjwal is Rs. 2.73 Crores. For project development Central Financial Assistance (CFA) of Rs. 2.43 Crores has been sanctioned by MNRE and Rs. 1.20 Crores has been released by MNRE directly to M/s Central Electronics Limited on 02.02.2012. Remaining expenditure will be borne by UJVN Limited. Solar Photo Voltaic (SPV) of 100 kWp capacity Power Plant at “ Ujjwal”, Dehradun has been commissioned in the month of December, 2012.

1.4.18 DPRs for installation of 50 kWp and 80 kWp Solar Photo Voltaic (SPV) Power Plants at Ganga Bhawan and Yamuna Bhawan have been submitted to MNRE for Central Finance Assistance (CFA) for funding these projects.

1.4.19 UJVN Ltd. also propose to install Solar Photo Voltaic (SPV) Power Plants in the long run at various Hydro Electric Projects and their Power Channels. Initial studies have been made by UJVN Ltd. about the possibilities of installation of 0.2 MWp to 5.26 MWp Solar PV Power Plants at existing Power Stations and capacities ranging from

Business Plan of UJVN Limited for Control Period

1.07 MWp to much higher capacities over canal banks (subject to Forest & Environment and UPID clearances) have been studied. Installation of Power Plants at some of these locations are proposed to be firmed up after seeing the efficacy of 100 kWp Solar Photo Voltaic (SPV) Power Plant commissioned at “Ujjwal" which has already been taken up is established.

1.4.20 UJVN Ltd. as indicated in the above sections is looking at various sources of generation to augment its existing generation. In the above sections the endeavor of UJVN Ltd. has been to apprise the Commission the status of its initiatives in this regard. UJVN Ltd. shall file before the Commission the initiatives planned by it as soon as they take some concrete shape. At that stage UJVNL shall file before the Commission technical, financial and commercial details of the project for its approval.

1.4.21 Note on Manpower Planning of UJVN Ltd. during the Control Period is enclosed as Annexure-16.

Business Plan of UJVN Limited for Control Period

2 CAPITAL EXPENDITURE PLAN – UPCOMING PROJECTS

Business Plan of UJVN Limited for Control Period

2.1 Vyasi Hydroelectric Project (120 MW)

2.1.1 Background:

2.1.1.1 Vyasi HE Project of 120 MW is located downstream of Lakhwar dam scheme in the district of Dehradun in Uttarakhand. The project is planned to be constructed on the river Yamuna. The work site is connected with rest of the country through railways, airport at Dehradun and road network.

2.1.1.2 Initially this project was started in 1979 by the State Govt. of Uttar Pradesh. Partial work on various components of the project such as abutment stripping of Vyasi dam, excavation of surface powerhouse at Hathiari, HRT and surge shaft had been carried out. The major civil works on this project was started in 1987 and which progressed till 1992 but thereafter, all works on this project have been stopped.

2.1.1.3 Later on erstwhile UPSEB prepared a DPR revising the project cost at March 96 price level and submitted to CWC/CEA for approval. MOU was signed between Uttarakhand Government authorities and NHPC on 1st November 2003 for execution of the remaining work. Later on GoU entrusted the implementation of Lakhwar & Vyasi HE project (420 MW) to UJVN Limited vide letter No. 1596/ l(2)/ 2008-04(8)/ 77/ 2003 dated 23.06.08. UJVN Limited initiated the process of taking over the project but NHPC requested GOI and GoU for reconsideration of the decision to take over the project . GoU again vide Letter No. 3326/ I(2)/ 2004-04(8)- 17/ 2008 dated 30.12.08 informed Secretary (Power), GoI of its decision that UJVN Limited will complete the remaining work of the project and the request of NHPC for reconsideration of this decision may not be considered. The GoU decided to start construction work at the project immediately.

2.1.2 Capital Expenditure:

Business Plan of UJVN Limited for Control Period

2.1.2.1 The estimated cost of the project at February 2010 price level is Rs. 936.23 Crores including IDC of 72.51 Crores and Rs. 6.55 Crores of Financing Charges. The project is estimated to get completed by December 2016. Capital expenditure of Rs. 500 Crores is projected to be incurred during the control period. The year wise phasing of the capital expenditure during the control period is shown in the table below:

Table 5: Capital Expenditure during Control Period – Vyasi Project

Rs.Crores upto FY 2013- FY 2014- FY 2015- after 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure 104.00 100.00 200.00 200.00 332.23 936.23

2.1.2.2 Details of the project cost are provided in the table on next page :

Business Plan of UJVN Limited for Control Period

Table 6: Capital Cost – Vyasi Project VYASI H. E. PROJECT (120 MW), UTTARAKHAND ABSTRACT OF COST (February 2010) S. No Description Amount (Rs. in Crores) A CIVIL WORKS 1 DIRECT CHARGES I - Works A - Preliminary 28.36 B - Land 32.52 C - Works 317.79 J - Power Plant Civil Works 172.57 K - Buildings 19.66 M - Plantation 1.00 O - Miscellaneous 16.61 P - Maintenance During Construction 5.44 Q - Special Tools and Plants 1.27 R - Communication 34.06 X - Environment and Ecology 23.34 Y - Losses on Stock 1.36 TOTAL OF I - WORKS 653.97

II - Establishment 49.72

III - Tools and Plants 1.00

IV - Suspense -

V- Receipt & Recoveries -0.94 TOTAL DIRECT CHARGES 703.74

2 INDIRECT CHARGES I - Capitalised Value of Abatement of Land Revenue 0.36 II - Audit & Accounts Charges 3.27 TOTAL INDIRECT CHARGES 3.63

TOTAL CIVIL WORKS 707.38

B ELECTRICAL WORKS 149.79

TOTAL COST (CIVIL + ELECTRICAL) 857.17 INTEREST DURING CONSTRUCTION 72.51 FINANCING CHARGES 6.55 TOTAL COST INCLUDING IDC & FINANCING CHARGES 936.23

Total 936.23

Business Plan of UJVN Limited for Control Period

2.1.2.3 Economic Analysis

The energy generation from the project with an installed capacity of 120 MW in stand-alone operation mode is estimated at 375.24 MU in a 90% dependable year with 95% machine availability and considering aquatic release of 2 cumec continuously.

Interest rate of 12%, financing charges of 1% of loan amount, RoE of 14%, depreciation is considered same as repayment schedule and O&M charges of 1.5% of capital cost is assumed. Based on the above assumptions, Levellised tariff in this mode from the project works out as Rs. 4.19 per unit (with 10.74% discounting factor).

The detailed working of the economic analysis is provided in Detailed Project Report.

2.1.2.4 Status Update of Capital Expenditure:

Environment clearance received for Vyasi Power Station has been transferred in favour of UJVN Limited by MOEF on 22.04.2010 after NHPC conveyed its NOC for the same. The case for transfer of Forest land in favour of UJVN Limited from Irrigation Department has since been processed and recommended at State level on 05.06.2012 for sending the proposal to MoEF, GOI for according final approval. The case has been submitted in MoEF on 14.06.2012. The proposal was discussed in the meeting of Forest Advisory Committee held on 17.08.2012. FAC has recommended the transfer of land in favour of UJVN Limited from Irrigation Department with certain conditions. The case for preparing Forest Proposal for diversion of additional Forest land in River bed area and area above underground works has been started.

Business Plan of UJVN Limited for Control Period

Earlier an R&R package was decided by GoU for Lakhwar Vyasi Project and provided to NHPC in August, 2004. Later in May, 2008 an R&R proposal for projects of UJVN Limited was submitted to GoU for approval. Based on the above R&R package for Vyasi Project is to be finalised by the GoU. The supplementary agreement was formally executed between UJVL Limited and M/s NPCC Limited on 06.03.2012. The prequalification of contractors for Dam & associated structures has been done. Process of review/ vetting of tender document with the help of consultancy firm for execution of balance dam work, which was prepared in house has been undertaken. Work for Consultancy service for Design Engineering of Vyasi Project has been awarded.

2.1.3 Financing of Capital Expenditure:

2.1.3.1 The project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of Rs. 500 Crores planned for the control period, debt component will be Rs. 350 Crores and equity contribution will be Rs. 150 Crores. Equity will be provided by GoU from budgetary support envisaged for UJVN Limited while debt is yet to be tied-up with financial institutions through a tender has been floated for debt tie-up. Year-wise allocation of debt and equity for the control period is provided in the table below:

Table 7: Funding Pattern during the Control Period – Vyasi Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Debt 72.80 70.00 140.00 140.00 232.56 655.36 Equity 31.20 30.00 60.00 60.00 99.67 280.87 Debt 70% 70% 70% 70% 70% 70% Equity 30% 30% 30% 30% 30% 30%

Business Plan of UJVN Limited for Control Period

2.1.4 Capitalization Schedule:

2.1.4.1 As per the Commissioning schedule, Vyasi project will get commissioned in December, 2016. The entire capital expenditure of Rs. 936.23 Crores will get capitalized in FY 2016-17. Year-wise capitalization during the control period is provided in the table below:

Table 8: Capex & Capitalization during the Control Period – Vyasi Project

Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure 104.00 100.00 200.00 200.00 332.23 936.23 Capitalization - - - - 936.23 936.23

Business Plan of UJVN Limited for Control Period

2.2 Lakhwar Multipurpose Project (300 MW)

2.2.1 Background

2.2.1.1 Lakhwar Project of 300 MW is located in the district of Dehradun. The project is planned to be constructed on the river Yamuna in Uttarakhand state. The work site is connected through railway and airport from Dehradun. Initially this project was started in 1979 by the State Govt. of Uttar Pradesh.

2.2.1.2 The construction of main works of the project was started through three major contractors in July 1987. However the progress of construction of the project works suffered due to paucity of funds and by the end of 1992, the construction works were stopped. Before stoppage of the project works, part works on various components of the project such as abutment stripping of Lakhwar dam, construction of diversion tunnel, part construction of underground powerhouse had been carried out.

2.2.1.3 After the project was handed over to GoU a revised DPR at March 96 price level was prepared and submitted to CWC / CEA for approval and the project was handed over to NHPC for early completion. However, due to acute shortage of power in Uttarakhand State, the State Govt. decided to get the project executed by UJVN Limited and the project was taken back from NHPC. The DPR has been again updated at Feb 2010 price level. CEA vide its letter dated 3rd September 2012 has estimated IDC and FC for the revised cost of power component of the project.

2.2.2 Capital Expenditure:

2.2.2.1 The approved cost of the project at May 2012 price level is Rs. 3966.51 Crores without considering IDC & Financing Charges. The indicated cost includes Irrigation component of Rs. 2578.23 Crores and Power component of Rs. 1388.28 Crores. CEA vide its letter dated 3rd September 2012 has communicated IDC of Rs. 190.82 Crores and FC of Rs. 11.13 Crores for the hard cost of power component of the

Business Plan of UJVN Limited for Control Period

project. Since the project has been declared as National Project by GOI, 90% of the cost of Irrigation and Water component will be given as Grant Assistance by GOI and 10% by the beneficiary states. The project is estimated to get completed by December, 2018. Capital expenditure of Rs. 530 Crores is projected to be incurred during the control period for the Power Component and Rs 830 Crores for the Water/ Irrigation Component. The year wise phasing of the capital expenditure during the control period is shown in the table below:

Table 9: Capital Expenditure during the Control Period – Lakhwar Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure (Power Component) 242.00 80.00 200.00 250.00 818.23 1,590.23 Capital Expenditure (Water/ Irrigation Component)* - 100.00 325.00 405.00 1,748.23 2,578.23* * 90% cost of Water/ Irrigation component will be provided as grant assistance by GoI and 10% cost of Water/ Irrigation component shall be borne by beneficiary states.

2.2.2.2 Details of the project cost are provided in the table on the next page :

Business Plan of UJVN Limited for Control Period

Table 10: Capital Cost – Lakhwar Project Lakhwar H. E. PROJECT (300 MW), UTTARAKHAND ABSTRACT OF COST (February 2010) S. No Description Amount (Rs. in Crores) A CIVIL WORKS 1 DIRECT CHARGES I - Works A - Preliminary 44.28 B - Land 142.92 C - Works 2,423.90 J - Power Plant Civil Works 263.04 K - Buildings 62.52 M - Plantation - O - Miscellaneous 73.71 P - Maintenance During Construction 32.86 Q - Special Tools and Plants 2.79 R - Communication 104.31 X - Environment and Ecology 35.77 Y - Losses on Stock 8.21 TOTAL OF I - WORKS 3,194.31

II - Establishment 309.81

III - Tools and Plants 35.85

IV - Suspense -

V- Receipt & Recoveries -1.15 TOTAL DIRECT CHARGES 3,538.83

2 INDIRECT CHARGES I - Capitalised Value of Abatement of Land Revenue 0.86 II - Audit & Accounts Charges 35.85 TOTAL INDIRECT CHARGES 36.72

TOTAL CIVIL WORKS 3,575.54

B ELECTRICAL WORKS 390.96

TOTAL COST (CIVIL + ELECTRICAL) 3,966.51 INTEREST DURING CONSTRUCTION FINANCING CHARGES TOTAL COST EXCLUDING IDC & FINANCING CHARGES 3,966.51

Total 3,966.51

Business Plan of UJVN Limited for Control Period

2.2.2.3 Economic Analysis

The energy generation from the project with an installed capacity of 300 MW in stand-alone mode operation has been estimated at 612.93 MU in a 90% dependable year with 95% machine availability.

The unit cost of energy at saleable Design Energy at Bus Bar, considering return of 14% on the Equity invested in Lakhwar Project at May 2012 Price Level with 35% of total Cost of the project apportioned towards power component works out as follows:

Total cost of project without IDC = Rs. 3966.51 Crores

Total cost for power (35% apportioned) = Rs 1388.28 Crores (without IDC)

= Rs. 1590.23 Crores (including IDC of Rs. 190.82 Crores and Rs. 11.13 Crores of FC)

Cost towards drinking water and Irrigation component = Rs. 2578.23 Crores

Considering Interest rate of 10% for Capex, working capital interest rate of 10.25%, RoE of 14%, depreciation is considered same as repayment schedule and O&M charges of 1.5% of capital cost with an escalation of 4%, Levellised tariff for the project works out as Rs. 3.40 (without IDC and FC charges). However the rate has been revised to 4.34 per unit for revised project cost with IDC and FC charges. This rate has been communicated by CEA through its letter dated 3rd September 2012.The letter of CEA is annexed as annexure 13.

The detailed working of the economic analysis is provided in the Detailed Project Report.

2.2.2.4 Status Update of Capital Expenditure:

Revised DPR with revised cost estimate based on price level of February, 2010 was submitted to CWC on 16th July, 2010.

Business Plan of UJVN Limited for Control Period

A copy of revised DPR has been sent to member States of Upper Yamuna River Board (UYRB) in 2010 and again in 2012 for their views/comments regarding sharing of benefits. Rajasthan & Delhi have submitted their acceptance regarding sharing the benefits as per the MoU of 1994. Chairman, UJVN Limited has requested Principal Secretary, Irrigation Department, Haryana and Chief Secretary, U.P. for expediting their replies regarding sharing of benefits in continuation to earlier requests of UJVN Limited. Replies to the comments of all the Directorates of CWC were submitted and clearances have been received. The Project has been cleared by the Technical Advisory Committee of CWC in its meeting held on 14.12.2012. The forest and environmental clearance was granted by Department of Environment Forest and Wild Life, GoI in October, 1986 and February, 1987 respectively. MOEF has conveyed continuation of earlier Environmental Clearance for Lakhwar project with additional conditions as specified by the EAC of MoEF. On their observations replies shall be submitted by UJVN Limited by February 2013. Case of transfer of forest land in favour of UJVN Limited from Irrigation Department, Uttarakhand shall be submitted by February 2013.

2.2.3 Financing of Capital Expenditure:

2.2.3.1 Project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of Rs. 530 Crores planned during the control period, debt will be Rs. 371 Crores and equity contribution will be Rs. 159 Crores. Equity will be provided by GoU from budgetary support envisaged for UJVN Limited while debt is yet to be tied-up with financial institutions. Year-wise allocation of debt and equity for the control period is provided in the table below:

Business Plan of UJVN Limited for Control Period

Table 11: Funding Pattern during the Control Period – Lakhwar Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Debt - 56.00 140.00 175.00 789.41 1,160.41 Equity 242.00 24.00 60.00 75.00 28.82 429.82 Debt 0% 70% 70% 70% 96% 73% Equity 100% 30% 30% 30% 4% 27%

2.2.4 Capitalization Schedule:

2.2.4.1 As per Commissioning schedule, Lakhwar project will get commissioned in December 2018. The entire capital expenditure of Rs. 1590.23 Crores will get capitalized in FY 2018-19. Year-wise capitalization during the control period is provided in the table below:

Table 12: Capex & Capitalization during the Control Period – Lakhwar Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure 242.00 80.00 200.00 250.00 818.23 1,590.23 Capitalization - - - - 1,590.23 1,590.23

Business Plan of UJVN Limited for Control Period

2.3 Kishau Multipurpose Project (660 MW)

2.3.1 Background

2.3.1.1 Kishau Dam Project would utilize the water of river Tons which is a major tributary of river Yamuna and forms boundary between Himachal Pradesh and Uttarakhand in most of its reaches in this region. The water stored in the Kishau reservoir shall be utilized for irrigation, power generation and to augment drinking water supply for National Capital Delhi.

2.3.1.2 The project with a proposed installation of 660 MW (4 x 165 MW) is envisaged to generate an annual energy of 1379 MU in a 90% dependable year with 95% of Installed Capacity.

2.3.2 Capital Expenditure:

2.3.2.1 The estimated cost of the project at June 2010 price level is Rs. 7193 Crores excluding IDC and Financing Charges and it comprises of Rs. 4509 Crores of Power component and Rs. 2684 Crores of Irrigation & Water component as per formula adopted by CWC committee constituted by MoWR in December 2002 . As the project has been declared as a National Project by GOI, 90% cost of Irrigation and Water component will be given as Grant Assistance by GOI and 10% by the beneficiary states. The project is estimated to get completed in a period of 109 months. Capital expenditure of Rs. 110 Crores is projected to be incurred during the control period for the Power Component and Rs 60 Crores for the Water/ Irrigation Component.. The year wise phasing of the capital expenditure during the control period is shown in the table on the next page :

Business Plan of UJVN Limited for Control Period

Table 13: Capital Expenditure during the Control Period – Kishau Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure (Power Component) - - 10.00 100.00 4,399.00 4,509.00 Capital Expenditure (Water / Irrigation Component) - - - 60.00 2,624.00 2,684.00 * 90% cost of Water/ Irrigation component will be provided as grant assistance by GoI and 10% cost of Water/ Irrigation component shall be borne by beneficiary states.

2.3.2.2 Details of the same are provided in the table on the next page :

Business Plan of UJVN Limited for Control Period

Table 14: Capital Cost – Kishau Project KISHAU MULTIPURPOSE H. E. PROJECT (660 MW), UTTARAKHAND ABSTRACT OF COST (June 2010) S. No Description Amount (Rs. in Crores) A CIVIL WORKS 1 DIRECT CHARGES I - Works A - Preliminary 164.51 B - Land 800.40 C - Works 4,184.60 J - Power Plant Civil Works 175.56 K - Buildings 150.11 M - Plantation 3.90 O - Miscellaneous 40.00 P - Maintenance During Construction 45.10 Q - Special Tools and Plants 22.01 R - Communication 71.71 X - Environment and Ecology 379.62 Y - Losses on Stock 11.28 TOTAL OF I - WORKS 6,048.80

II - Establishment 100.00

III - Tools and Plants 60.49

IV - Suspense -

V- Receipt & Recoveries -8.07 TOTAL DIRECT CHARGES 6,201.22

2 INDIRECT CHARGES I - Capitalised Value of Abatement of Land Revenue 15.37 II - Audit & Accounts Charges 15.12 TOTAL INDIRECT CHARGES 30.49

TOTAL CIVIL WORKS 6,231.72

B ELECTRICAL WORKS 961.52

TOTAL COST (CIVIL + ELECTRICAL) 7,193.24

TOTAL COST EXCLUDING IDC & FINANCING CHARGES 7,193.24

Business Plan of UJVN Limited for Control Period

2.3.2.3 Economic Analysis

Finalization of the project cost is under process and currently project cost excluding IDC & financing charges is available. After IDC & financial charges have been finalized, economic evaluation will be carried out for the project.

2.3.2.4 Status Update of Capital Expenditure:

Revised DPR with cost estimate based on price level of June, 2010 was submitted by UJVN Limited to CWC on 15th October, 2010. A copy of revised DPR has been sent to member States of UYRB in 2010 and again in 2012 for their views/comments regarding sharing of benefits. Rajasthan & Delhi have submitted their acceptance regarding sharing of the benefits as per the MoU of 1994. Chairman, UJVN Limited has requested Principal Secretary, Irrigation Department, Haryana and Chief Secretary, U.P. for expediting their replies regarding sharing of benefits in continuation to earlier requests of UJVN Limited. Comments from various Directorates of CWC/CEA are being replied by UJVN Limited. Further, persuasion/ discussion/ replies shall be expedited on nomination of JV partner by GoHP. Proposal for issue of TOR for EIA/EMP studies of the project was submitted to MoEF on 25th February, 2011. The agency for EIA/EMP studies shall be finalized after nomination of JV partner by GoHP for which correspondences/ Discussion/ meetings have been undertaken with Principal Secretary (Power), GoHP and others on various occasions.

2.3.3 Financing of Capital Expenditure:

2.3.3.1 The project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of Rs. 110 Crores planned for the control period, debt will be Rs. 77 Crores and equity

Business Plan of UJVN Limited for Control Period

contribution will be Rs. 33 Crores Equity contribution will be 50% from UJVN Limited and 50% by JV partner to be nominated by GoHP. The equity contribution by UJVN Limited will be considered as investment in its books of accounts. Equity will be provided from budgetary support of GoU while debt is yet to be tied-up with financial institutions. Year-wise allocation of debt and equity for the control period is provided in the table below:

Table 15: Funding Pattern during the Control Period – Kishau Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Debt - JV - - 7.00 70.00 3,079.30 3,156.30 Equity - UJVNL - - 1.50 15.00 659.85 676.35 Equity - JV Partner - - 1.50 15.00 659.85 676.35 Debt - JV 0% 0% 70% 70% 70% 70% Equity - UJVNL 15.00% 15.00% 15.00% 15.00% 15.00% 15.00% Equity - JV Partner 15.00% 15.00% 15.00% 15.00% 15.00% 15.00%

2.3.4 Capitalization Schedule:

2.3.4.1 As per Commissioning schedule, Kishau project will get commissioned in March 2024. The entire capital expenditure of Rs. 4509 Crores (excluding IDC & Financing Charges) will get capitalized in FY 2023-24. Year-wise capitalization during the control period is provided in the table below:

Table 16: Capex & Capitalization during the Control Period – Kishau Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - - 10.00 100.00 4,399.00 4,509.00

Capitalization - - - - 4,509.00 4,509.00

Business Plan of UJVN Limited for Control Period

2.4 Sirkari Bhyol Rupsiabagar Hydroelectric Project (210 MW)

2.4.1 Background

2.4.1.1 Sirkari Bhyol Rupsiabagar Hydroelectric Project is located in Pithoragarh district of Uttarakhand and it envisages utilization of the waters of the river Goriganga, a tributary of river Kali (Sarda) for power generation as a run of river scheme, harnessing a head of about 388.97 m.

2.4.1.2 The project with a proposed installation of 210 MW (3 x 70 MW) is envisaged to generate an annual energy of 967.97 MU in a 90% dependable year with 95% Installed capacity.

2.4.2 Capital Expenditure:

2.4.2.1 The estimated cost of the project at June 2003 price level is Rs. 893.63 Crores including IDC & Financing Charges of Rs. 141.07 Crores. The project is estimated to get completed in a period of 66 months. Capital expenditure of Rs. 5 Crores is projected to be incurred during the control period. The year wise phasing of the capital expenditure during the control period is shown in the table below:

Table 17: Capital Expenditure during the Control Period – Sirkari Bhyol Rupsiabagar Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - - - 5.00 888.63 893.63

2.4.2.2 Details of the project cost are provided in the table on the next page :

Business Plan of UJVN Limited for Control Period

Table 18: Capital Cost – Sirkari Bhyol Rupsiabagar Project SARKARI BHYOL RUPSIABAGAR H. E. PROJECT (210 MW), UTTARAKHAND ABSTRACT OF COST (June 2003) S. No Description Amount (Rs. in Crores) A CIVIL WORKS 1 DIRECT CHARGES I - Works A - Preliminary 8.60 B - Land 1.80 C - Works 276.50 J - Power Plant Civil Works 151.20 K - Buildings 17.20 M - Plantation 2.00 O - Miscellaneous 17.20 P - Maintenance During Construction 4.62 Q - Special Tools and Plants 10.00 R - Communication 17.20 X - Environment and Ecology 8.60 Y - Losses on Stock -1.16 TOTAL OF I - WORKS 513.76

II - Establishment 40.96

III - Tools and Plants 5.14

IV - Suspense 5.14

V- Receipt & Recoveries -4.08 TOTAL DIRECT CHARGES 555.78

2 INDIRECT CHARGES I - Capitalised Value of Abatement of Land Revenue 0.09 II - Audit & Accounts Charges 5.14 TOTAL INDIRECT CHARGES 5.23

TOTAL CIVIL WORKS 561.01

B ELECTRICAL WORKS 191.55

TOTAL COST (CIVIL + ELECTRICAL) 752.56 INTEREST DURING CONSTRUCTION 141.07 FINANCING CHARGES - TOTAL COST INCLUDING IDC & FINANCING CHARGES 893.63

Total 893.63

Business Plan of UJVN Limited for Control Period

2.4.2.3 Economic Analysis

The energy generation from the project with an installed capacity of 210 MW in stand-alone operation mode is estimated at 967.97 MU in a 90% dependable year with 95% machine availability.

Considering Interest rate of 10%, RoE of 14%, depreciation is considered same as repayment schedule and O&M charges of 1.5% of capital cost with escalation rate of 5% the, Levellised tariff of the project works out as Rs. 1.25 per unit (with 12.00% discounting factor).

The detailed working of the economic analysis is provided in the Detailed Project Report.

2.4.2.4 Status Update of Capital Expenditure:

Preparation of comprehensive and bankable DPR of Sirkari Bhyol Rupsiabagar Power Station is under progress. Work for conducting geological investigations has been awarded on 27.04.2012 and mobilisation of resources for the same at the project site is in progress. DPR consultant has been requested for finalisation of Layout of the Project. After finalisation of layout and salient features of various components of the Project, revised ToR for conducting EIA/EMP studies shall be sought from MoEF.

2.4.3 Financing of Capital Expenditure:

2.4.3.1 This Project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of Rs. 5 Crores planned for the control period, debt will be Rs. 3.5 Crores and equity contribution will be Rs. 1.5 Crores. Equity will be provided from budgetary support of GoU for UJVN Limited while debt is yet to be tied-up with financial institutions.

Business Plan of UJVN Limited for Control Period

Year-wise allocation of debt and equity for the control period is provided in the table below:

Table 19: Funding Pattern during the Control Period – Sirkari Bhyol Rupsiabagar Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Debt - - - 3.50 622.04 625.54 Equity - - - 1.50 266.59 268.09 Debt 0% 0% 0% 70% 70% 70% Equity 0% 0% 0% 30% 30% 30%

2.4.4 Capitalization Schedule:

2.4.4.1 As per Commissioning schedule, Sirkari Bhyol Rupsiabagar project will get commissioned in June, 2021. The entire capital expenditure of Rs. 893.63 Crores will get capitalized in FY 2020-21. Year-wise capitalization during the control period is provided in the table below:

Table 20: Capex & Capitalization during the Control Period –Sirkari Bhyol Rupsiabagar Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - - - 5.00 888.63 893.63 Capitalization - - - - 893.63 893.63

Business Plan of UJVN Limited for Control Period

2.5 Bowala Nand Prayag Hydroelectric Project (300 MW)

2.5.1 Background:

2.5.1.1 The Bowala Nand Prayag Hydro Electric Power Project is located in Chamoli district of Uttarakhand State on the Alaknanda River, near to Chamoli and some 25 km downstream of Josimath. The Alaknanda River is one of the main tributaries of the Ganga. The Project can be approached via a 200 km long drive from Rishikesh on National Highway 58 which goes up to Badrinath, the road is metalled right up to the project site.

2.5.1.2 The project with a proposed installation of 300 MW (4 x 75 MW) is envisaged to generate an annual energy of 1340 MU in a 90% dependable year with 95% of the Installed Capacity.

2.5.2 Capital Expenditure:

2.5.2.1 The estimated cost of the project at May 2012 price level is Rs. 3007.24 Crores including IDC of 612.39 Crores and Rs. 290.35 Crores for Financing Charges. The project is estimated to get completed in a period of 60 months. Capital expenditure of Rs. 305 Crores is projected to be incurred during the control period. The year wise phasing of the capital expenditure during the control period is shown in the table below:

Table 21: Capital Expenditure during the Control Period – Bowala Nand Prayag Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - 5.00 100.00 200.00 2,702.24 3,007.24

2.5.2.2 Details of the project cost are provided in the table on the next page :

Business Plan of UJVN Limited for Control Period

Table 22: Capital Cost – Bowala Nand Prayag Project BOWALA NNANDPRAYAG H. E. PROJECT (300 MW), UTTARAKHAND ABSTRACT OF COST (May 2012) S. No Description Amount (Rs. in Crores) A CIVIL WORKS 1 DIRECT CHARGES I - Works A - Preliminary 20.69 B - Land 34.67 C - Works 763.52 J - Power Plant Civil Works 573.81 K - Buildings 38.66 M - Plantation 0.65 O - Miscellaneous 34.23 P - Maintenance During Construction 14.10 Q - Special Tools and Plants 5.76 R - Communication 33.62 X - Environment and Ecology 48.56 Y - Losses on Stock 3.52 TOTAL OF I - WORKS 1,571.78

II - Establishment 104.20

III - Tools and Plants 15.72

IV - Suspense -

V- Receipt & Recoveries -3.33 TOTAL DIRECT CHARGES 1,688.37

2 INDIRECT CHARGES I - Capitalised Value of Abatement of Land Revenue 0.20 II - Audit & Accounts Charges 15.72 TOTAL INDIRECT CHARGES 15.92

TOTAL CIVIL WORKS 1,704.30

B ELECTRICAL WORKS 400.20

TOTAL COST (CIVIL + ELECTRICAL) 2,104.50 INTEREST DURING CONSTRUCTION 612.39 FINANCING CHARGES 290.35 TOTAL COST INCLUDING IDC & FINANCING CHARGES 3,007.24

Total 3,007.24

Business Plan of UJVN Limited for Control Period

2.5.2.3 Economic Analysis

With the Design Energy of 1340 GWh, 0.2% as auxiliary consumption and 0.5% as transformation losses, saleable energy is 1330.62 GWh per annum.

Levelised Tariff

Considering interest rate of 10.25%, RoE of 14%, depreciation is considered same as loan repayment schedule and O&M charges of 1.5% of capital cost with escalation of 4% the levelised tariff calculated in accordance with the CERC guidelines is Rs 2.35/kWh and the tariff for the first year of operation is Rs 3.24/kWh.

Benefit: Cost Ratio

The Net Present Values of costs and benefits based on the 90% dependable year’s energy and with a fixed tariff of Rs 2.50/kWh work out to be as follows (after tax):

Rs. Lakhs

NPV of Benefit (90% Year) 1,08,530

NPV of Cost (90% Year) 1,04,026

Benefit / Cost (90% Year) 1.04

Net Benefit (90% Year) 4,504

The detailed working of the economic analysis is provided in Detailed Project Report.

2.5.2.4 Status Update of Capital Expenditure:

The project DPR with enhanced capacity of 300 MW has been submitted to CEA for concurrence on 18th July 2007. Most of the chapters of the DPR have been cleared by CEA/ CWC. Revised final DPR prepared in 6 volumes has been

Business Plan of UJVN Limited for Control Period

submitted to CEA in 22 sets for Techno Economic Concurrence on 18th August, 2012. Techno Economic Clearance (TEC) from CEA is expected by February, 2013. Report of EIA/EMP studies conducted by M/s Rites has been submitted by UJVN Limited to MoEF in April, 2011 for permission to conduct public hearing. Public hearing was conducted through State Pollution Control Board (SPCB) on 23.08.12 and as decided another Public hearing shall be held in February, 2013 for which requisite fee has been deposited with SPCB on 23.11.12. The approval of GoU to execute Bowla Nand Prayag & Nand Prayag Langasu Projects through Joint Venture through open bidding process has been received vide letter no. 2302/I(2)/2011-04/(3)/11/2006 dated 24.11.2011. RFQ cum RFP document, Joint Venture Agreement & Share Holding Agreement have been finalised and submitted to GoU for approval on 18.01.2012.

2.5.3 Financing of Capital Expenditure:

2.5.3.1 The Project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of Rs. 305 Crores planned during the control period, debt will be Rs. 213.5 Crores and equity contribution will be Rs. 91.5 Crores. Equity will be provided from budgetary support of GoU envisaged for UJVN Limited while debt is yet to be tied- up with financial institutions. Equity contribution will be 26% from UJVN Limited and 74% by JV partner. Free equity offered by the probable JV partner over and above 10% threshold equity to UJVN Limited will be the basis of selecting the JV partner, thus UJVN Limited will be required to invest 16% or less of the equity component in the project. The equity contribution by UJVN Limited will be considered as investment in its books of accounts. Year-wise allocation of debt and equity for the control period is provided in the table below:

Business Plan of UJVN Limited for Control Period

Table 23: Funding Pattern during the Control Period – Bowla Nand Prayag Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Debt - JV - 3.50 70.00 140.00 1,891.57 2,105.07 Equity - UJVNL - 0.39 7.80 15.60 210.77 234.56 Equity - JV Partner - 1.11 22.20 44.40 599.90 667.61 Debt - JV 0% 70% 70% 70% 70% 70% Equity - UJVNL 0.00% 7.80% 7.80% 7.80% 7.80% 7.80% Equity - JV Partner 0.00% 22.20% 22.20% 22.20% 22.20% 22.20%

2.5.4 Capitalization Schedule:

2.5.4.1 As per the existing commissioning schedule, Bowla Nand Prayag Project will get commissioned in March, 2019. The entire capital expenditure of Rs. 3007.24 Crores will get capitalized in FY 2018-19. Year-wise capitalization during the control period is provided in the table below:

Table 24: Capex & Capitalization during the Control Period – Bowla Nand Prayag Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - 5.00 100.00 200.00 2,702.24 3,007.24

Capitalization - - - - 3,007.24 3,007.24

Business Plan of UJVN Limited for Control Period

2.6 Nand Prayag Langasu Hydroelectric Project (100 MW)

2.6.1 Background:

2.6.1.1 Nand Prayag Langasu Hydroelectric project located on the New Delhi – Badarinath National Highway No. 58 almost midway between Karanprayag and Nandprayag in Chamoli district of Uttarakhand State. The project envisages utilization of the water of river Alaknanda for power generation on a run of the river scheme harnessing a gross head of about 80 m.

2.6.1.2 The project with a proposed installation of 100 MW (4 x 25 MW) is envisaged to generate an annual energy of 490.45 MU in a 90% dependable year with 95% of the Installed Capacity.

2.6.2 Capital Expenditure:

2.6.2.1 The estimated cost of the project at August 2010 price level is Rs. 1401.19 Crores including IDC & Financing Charges of 261.00 Crores. The project is estimated to get completed in a period of 66 months. Capital expenditure of Rs. 105 Crores is projected to be incurred during the control period. The year wise phasing of the capital expenditure during the control period is shown in the table below:

Table 25: Capital Expenditure during the Control Period – Nand Prayag Langasu Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - - 5.00 100.00 1,296.19 1,401.19

2.6.2.2 Details of the project cost are provided in the table on the next page :

Business Plan of UJVN Limited for Control Period

Table 26: Capital Cost – Nand Prayag Langasu Project

NANDPRAYAG LANGASU H. E. PROJECT (100 MW), UTTARAKHAND ABSTRACT OF COST August 2010) S. No Description Amount (Rs. in Crores) A CIVIL WORKS 1 DIRECT CHARGES I - Works A - Preliminary 11.92 B - Land 3.45 C - Works 228.28 J - Power Plant Civil Works 598.99 K - Buildings 2.07 M - Plantation 0.18 O - Miscellaneous 7.08 P - Maintenance During Construction 8.29 Q - Special Tools and Plants 3.85 R - Communication 2.97 X - Environment and Ecology 22.46 Y - Losses on Stock 2.07 TOTAL OF I - WORKS 891.61

II - Establishment 69.26

III - Tools and Plants 2.50

IV - Suspense -

V- Receipt & Recoveries -1.57 TOTAL DIRECT CHARGES 961.80

2 INDIRECT CHARGES I - Capitalised Value of Abatement of Land Revenue 0.09 II - Audit & Accounts Charges 4.46 TOTAL INDIRECT CHARGES 4.55

TOTAL CIVIL WORKS 966.34

B ELECTRICAL WORKS 173.85

TOTAL COST (CIVIL + ELECTRICAL) 1,140.19 INTEREST DURING CONSTRUCTION 261.00 FINANCING CHARGES - TOTAL COST INCLUDING IDC & FINANCING CHARGES 1,401.19

Total 1,401.19

Business Plan of UJVN Limited for Control Period

2.6.2.3 Economic Analysis

The energy generation from the project with an installed capacity of 100 MW in stand-alone operation mode is estimated at 490.45 MU in a 90% dependable year with 95% machine availability.

Considering Interest rate of 8.50% for capital, interest rate of 12.00% for working capital, RoE of 14%, depreciation is considered same as repayment schedule and O&M charges of 2.00% of capital cost with escalation of 5.72% the Levellised tariff from the project works out as Rs. 4.19 per unit (with 12.00% discounting factor).

The detailed working of the economic analysis is provided in Detailed Project Report.

2.6.2.4 Status Update of Capital Expenditure:

Updated DPR with approved hydrology was submitted to CEA on 5th March, 2011. A presentation in CEA along with the consultant M/s Tractebal Engineers Limited was given on 04.04.2011 in the presence of various Directors of CEA/CWC on Nand Prayag Langasu project. The observations/comments of various directorates of CEA/CWC have been received and will be replied in due course. With regard to comments of GSI, a joint site visit of Geologists of UJVN Limited & the consultant was conducted in January, 2012 & replies have been submitted on 25.04.2012. Revised ToR has been issued by MOEF. As per revised ToR, EIA/EMP studies are to be conducted by accredited institutions registered with Quality Council of India/ NABET. Work for EIA/ EMP studies based upon revised TOR conveyed by MoEF was awarded on 26.6.12 and the same is to be completed by December 2013.

Business Plan of UJVN Limited for Control Period

The approval of GoU has been received vide letter no. 2302/I(2)/2011- 04/(3)/11/2006 dated 24.11.2011 to execute Bowla Nand Prayag & Nand Prayag Langasu Projects through Joint Venture through open bidding process. RFQ cum RFP document, Joint Venture Agreement & Share Holding Agreement have been finalised and submitted on 18.01.2012 to GoU for approval.

2.6.3 Financing of Capital Expenditure:

2.6.3.1 The Project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of Rs. 105 Crores planned during the control period, debt will be Rs. 73.5 Crores and equity contribution will be Rs. 31.5 Crores. Equity will be provided from budgetary support of GoU envisaged for UJVN Limited while debt is yet to be tied-up with financial institutions. Equity contribution will be 26% from UJVN Limited and 74% by JV partner. Free equity offered by the probable JV partner over and above 10% threshold equity to UJVN Limited will be the basis of selecting the JV partner, thus UJVN Limited will be required to invest 16% or less of the equity component in the project. The equity contribution by UJVN Limited will be considered as investment in its books of accounts. Year-wise allocation of debt and equity for the control period is provided in the table below:

Table 27: Funding Pattern during the Control Period – Nand Prayag Langasu Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Debt - JV - - 3.50 70.00 907.33 980.83 Equity - UJVNL - - 0.39 7.80 101.10 109.29 Equity - JV Partner - - 1.11 22.20 287.75 311.06 Debt - JV 0% 0% 70% 70% 70% 70% Equity - UJVNL 0.00% 0.00% 7.80% 7.80% 7.80% 7.80% Equity - JV Partner 0.00% 0.00% 22.20% 22.20% 22.20% 22.20%

Business Plan of UJVN Limited for Control Period

2.6.4 Capitalization Schedule:

2.6.4.1 As per the present commissioning schedule, Nand Prayag Langasu project will get commissioned in March 2020. The entire capital expenditure of Rs. 1401.19 Crores will get capitalized in FY 2019-20. Year-wise capitalization during the control period is provided in the table below:

Table 28: Capex & Capitalization during the Control Period – Nand Prayag Langasu Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - - 5.00 100.00 1,296.19 1,401.19

Capitalization - - - - 1,401.19 1,401.19

Business Plan of UJVN Limited for Control Period

2.7 Tamak Lata Hydroelectric Project (250 MW)

2.7.1 Background:

2.7.1.1 Tamak-Lata Hydroelectric Project is planned as a Run–of–River Project on river Dhauliganga to develop a rated head of about 291.4 m between barrage site at Tamak village and Powerhouse site at village Lata in Joshimath Tehsil of Chamoli District of Uttarakhand. The barrage site will be located immediately downstream of Tailrace out fall from Powerhouse of Jhelam-Tamak H.E. Project. The underground Power house complex is proposed to be located near village Lata upstream barrage site of Lata Tapovan project.

2.7.1.2 The project with a proposed installation of 250 MW (4 x 62.5 MW) is envisaged to generate an annual energy of 1041.43 MU in a 90% dependable year with 95% Installed Capacity.

2.7.2 Capital Expenditure:

2.7.2.1 The estimated cost of the project at November 2007 price level is Rs. 1053.45 Crores excluding IDC & Financing Charges. The project is estimated to get completed in a period of 42 months. Capital expenditure of Rs. 52 Crores is projected to be incurred during the control period. The year wise phasing of the capital expenditure during the control period is shown in the table below:

Table 29: Capital Expenditure during the Control Period – Tamak Lata Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - - 2.00 50.00 1,001.45 1,053.45

2.7.2.2 Details of the project cost are provided in the table on the next page :

Business Plan of UJVN Limited for Control Period

Table 30: Capital Cost – Tamak Lata Project TAMAKLATA H. E. PROJECT (250 MW), UTTARAKHAND ABSTRACT OF COST (November 2007) S. No Description Amount (Rs. in Crores) A CIVIL WORKS 1 DIRECT CHARGES I - Works A - Preliminary 24.25 B - Land 19.83 C - Works 198.85 J - Power Plant Civil Works 373.65 K - Buildings 8.59 M - Plantation 0.95 O - Miscellaneous 11.78 P - Maintenance During Construction 6.38 Q - Special Tools and Plants 7.04 R - Communication 25.70 X - Environment and Ecology 14.20 Y - Losses on Stock - TOTAL OF I - WORKS 691.22

II - Establishment 33.35

III - Tools and Plants 6.91

IV - Suspense -

V- Receipt & Recoveries - TOTAL DIRECT CHARGES 731.48

2 INDIRECT CHARGES I - Capitalised Value of Abatement of Land Revenue - II - Audit & Accounts Charges 6.91 TOTAL INDIRECT CHARGES 6.91

TOTAL CIVIL WORKS 738.39

B ELECTRICAL WORKS 315.05

TOTAL COST (CIVIL + ELECTRICAL) 1,053.45

TOTAL COST EXCLUDING IDC & FINANCING CHARGES 1,053.45

Business Plan of UJVN Limited for Control Period

2.7.2.3 Economic Evaluation

Finalization of the project cost is under process and currently project cost excluding IDC & financing charges is available. After IDC & financial charges have been calculated, economic evaluation will be carried out for the project.

2.7.2.4 Status Update of Capital Expenditure:

Draft DPR of the project has been submitted by the consultant. Hydrology has been cleared by CWC in September, 2011. During presentation before MoEF, EAC advised for reduction of Length of HRT for free stretch of flow of river for at least 1-2 Km. in this regard consultations with THDC officials were undertaken. Additional study for alternative site for location of powerhouse has been conducted & after finalization of free riverine stretch by MoEF, revision of DPR shall be undertaken. As desired by MoEF revised power potential studies of Malari Jhelum, Jhelum Tamak (both under development by THDC) and Tamak Lata were submitted by THDC to MoEF on 18.04.2012. Further, replies to the observations of Expert Appraisal Committee (EAC) for providing ToR for conducting EIA/EMP studies have been framed and same will be submitted to MoEF in due course. The approval of GoU to execute Tamak Lata Project through Joint Venture through open bidding process has been received vide letter no. 2302/I(2)/2011-04/(3)/11/2006 dated 24.11.2011. RFQ cum RFP document, Joint Venture Agreement & Share Holding Agreement have been finalised and submitted to GoU for approval on 15.02.2012.

2.7.3 Financing of Capital Expenditure:

2.7.3.1 The Project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of Rs. 52 Crores planned during the control period, debt will be Rs. 36.4 Crores and equity contribution will be Rs. 15.6 Crores. Equity will be provided from the

Business Plan of UJVN Limited for Control Period

budgetary support of GoU envisaged for UJVN Limited while debt is yet to be tied- up with financial institutions. Equity contribution will be 26% from UJVN Limited and 74% by JV partner. Free equity offered by the probable JV partner over and above 10% threshold equity to UJVN Limited will be the basis of selecting the JV partner, thus UJVN Limited will be required to invest 16% or less of the equity component in the project. The equity contribution by UJVN Limited will be considered as investment in its books of accounts. Year-wise allocation of debt and equity for the control period is provided in the table below:

Table 31: Funding Pattern during the Control Period – Tamak Lata Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Debt - JV - - 1.40 35.00 701.02 737.42 Equity - UJVNL - - 0.16 3.90 78.11 82.17 Equity - JV Partner - - 0.44 11.10 222.32 233.87 Debt - JV 0% 0% 70% 70% 70% 70% Equity - UJVNL 0.00% 0.00% 7.80% 7.80% 7.80% 7.80% Equity - JV Partner 0.00% 0.00% 22.20% 22.20% 22.20% 22.20%

2.7.4 Capitalization Schedule:

2.7.4.1 As per present Commissioning schedule, Tamak Lata project will get commissioned in March 2019. The entire capital expenditure of Rs. 1053.45 Crores excluding IDC & Financing charges will get capitalized in FY 2018-19. Year-wise capitalization during the control period is provided in the table below:

Table 32: Capex & Capitalization during the Control Period – Tamak Lata Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - - 2.00 50.00 1,001.45 1,053.45

Capitalization - - - - 1,053.45 1,053.45

Business Plan of UJVN Limited for Control Period

2.8 Pala Maneri Hydroelectric Project (480 MW)

1 Proposed Capacity (MW) 480(4x120)

2 River/District Bhagirathi/Uttarkashi

3 Date of allocation to UJVNL 21.04.2003

4 Annu. Energy Generation( MU) 1993

5 Project Cost (in Rs Crore) 1922.8 (PL- Feb,2007)

6 Tariff (Rs per unit) 1.71

7 MOEF-Ist stage clearance 07.12.2005

8 Detailed Project Report DPR was submitted to CEA/CWC on 04.07.2005, which submission and clearance was Updated and revised as per requirement of CWC and further submitted on November, 2006. Techno- economic concurrence (TEC) by CEA was accorded on 23.02.2007. 9 Present status of work Pre-construction works related to the project i.e. construction power, construction of road, detailed Investigation, detailed design engineering & colony maintenance were started for early implementation of the Project. Works related to acquisition of private land, govt. land and diversion of forest land etc. were also taken up. The contracts for major works of the project were also prepared. The project is discontinued by Government of India on the basis of meeting of National Ganga River Basin Authority (NGRBA) held on dated 01.11.2010 as communicated by GoU vide letter no. 03/I(2)/2010- 04(8)/52/2008 dated 03.01.2011. Proposal for approval of foreclosure of existing contracts in a safe and logical manner with a minimum expenditure of Rs. 15.67 crores was presented in the 60th Board meeting held on 07.09.2011 for recommendation / approval. Board approved the same and further advised to forward it to Government for their final approval/consent and fund allocation. Accordingly, a proposal was forwarded to GoU for final approval and fund allocation on 01.10.2011. Total expenditure incurred on the project till date is Rs. 111.89 Crores.

Business Plan of UJVN Limited for Control Period

2.9 Bhaironghati Hydroelectric Project (381 MW)

1 Proposed Capacity (MW) 381 (3x127)

2 River/District Bhagirathi/Uttarkashi

3 Date of allocation to UJVNL 06.10.2005

Annual Energy Generation( 4 1406.20 MU)

5 Project Cost (in Rs Crore) 2033.37 (PL-June,2007)

6 Tariff (Rs per unit) 2.00

7 MOEF-1st stage clearance 13.09.2005 Work of DPR and EIA/EMP studies was assigned by GoU to M/s Canadian Commercial Corporation in Feb 2004 with SNC Lavalin as their Executing agency. DPR was submitted to CEA /CWC for concurrence in 8 DPR work & its submission Jan’2008. Hydrology, Electromechanical, Hydro- mechanical equipment design chapters etc. have been cleared. For concurrence on Geology, civil design and foundation engineering additional Geo- technical investigation are required. The project is discontinued by Government of India on the basis of meeting of National Ganga River Basin Authority (NGRBA) held on dated 01.11.2010 as communicated by GoU vide letter no. 9 Present status of work 03/I(2)/2010-04(8)/52/2008 dated 03.01.2011. Total expenditure incurred till date on the project is Rs. 20.92 Crores. Committed liabilities on the Project amounts to Rs. 3.8 Crores.

Business Plan of UJVN Limited for Control Period

3 CAPITAL EXPENDITURE PLAN – EXISTING PROJECTS

Business Plan of UJVN Limited for Control Period

3.1 Chibro Power Station (240 MW)

3.1.1 Background:

3.1.1.1 Chibro Power Station is a Run-of-River scheme with an underground Power Station. It was the first underground Power Station in the North India and was commissioned in the year 1975. The Power Station draws water from Ichari dam located on the river Tons, one of the major tributary of river Yamuna.

3.1.1.2 Chibro Power Station is a unique engineering marvel in the country and was the first experience in carrying out tunnelling in the Himalayan Thrust Zones, which was a challenge due to varied rock structure and strength. There were unexpected challenges in the tunnelling effort. The water from Ichari Dam is fed into the Power Station through a 6.2 km long Head Race Tunnel (HRT). The Power Station comprising of 4 units of 60 MW each with Francis turbines of 62.66 MW output, is housed in a rock cavern with the major challenge of maintaining fresh air and safety measures due to constraint of space. Design head of the project is 110m.

3.1.1.3 On 5th of March 2008, UJVN Limited entrusted the Consultant, Lahmeyer International GmbH., with a comprehensive study for the modernisation and upgradation of the station. The study is financed by the Kreditanstalt fur Wiederaufbau (KfW), Germany.

3.1.2 Capital Expenditure:

3.1.2.1 Capital Expenditure for RMU works is estimated at Rs. 184.88 Crores. Capital expenditure of Rs. 27.73 Crores is projected to be incurred during the control period. The year wise phasing of the capital expenditure during the control period is shown in the table below:

Table 33: Capital Expenditure during the Control Period – Chibro Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - - - 27.73 157.15 184.88

Business Plan of UJVN Limited for Control Period

3.1.2.2 RMU Project

Primary purpose of RMU is life extension of the project apart from increase in generation. After RMU, generation will increase from 865 MU to 942 MU (as per DPR) subject to same water discharge. Details of the total cost are provided in the table on the next page :

Business Plan of UJVN Limited for Control Period

Table 34: Capital Cost – Chibro Project CHIBRO H. E. PROJECT (240 MW), UTTARAKHAND ABSTRACT OF COST S. No Description Amount (Rs. in Crores) 1 DIRECT CHARGES I - Works A - Preliminary 1.43 B - Land - C - Works C1 - Civil Works 3.06 C2 - Hydrulic Steel Structures 6.67 J - Power Plant Civil Works J1 - Civil Works 2.27 J2 - Hydrulic Steel Structures 2.85 K - Buildings - M - Plantation - O - Miscellaneous 4.28 P - Maintenance During Construction 0.15 Q - Special Tools and Plants 0.10 R - Communication - S - Power Plant S1 - Mechanical Equipment 49.63 S2 - Electrical Equipment 77.79 X - Environment and Ecology 0.13 Y - Losses on Stock 0.04 TOTAL OF I - WORKS 148.39

II - Establishment 11.87 III - Tools and Plants 1.48 IV - Suspense - V- Receipt & Recoveries -0.02 TOTAL DIRECT CHARGES 161.73

2 INDIRECT CHARGES I - Capitalised Value of Abatement of Land Revenue - II - Audit & Accounts Charges 0.37 TOTAL INDIRECT CHARGES 0.37

TOTAL COST (Direct & Indirect Cost) 162.10

Escalation till start of M&U Measure 18.92 IDC 2.91 Commitment Fees 0.72 Up-front Fees - Guarantee Fees 0.22 Total 184.88

Business Plan of UJVN Limited for Control Period

3.1.2.3 Economic and Environmental Impact Evaluation

The economic feasibility of the RM&U project for Chibro Power Station was appraised based on the following economic indicators:

The Economical Internal Rate of Return (EIRR) which represents the rate of return that equates the present value of costs with the present value of benefits; The Economic Net Present Value (ENPV) which derived by discounting the net benefits; The benefit-cost-ratio which represents the ratio between the present value of benefits and the present value of costs.

An economic discount rate of ten percent (10%) was used in the appraisal of the economic feasibility. Results are summarised below:

RESULTS

Site Chibro Power Station

Economic Discount Rate 10.00%

EIRR (%) 30.08%

ENPV (Rs. Crores) 406.14

B/C Ratio 2.92

These results lead to the conclusion that the modernization and upgradation of the Chibro Power Station is an economically feasible project. The conclusion is drawn due to the following observations:

The EIRR is greater than the assumed economic discount rate of 10% The ENPV is greater than zero. The benefit-cost ratio is greater than one.

Business Plan of UJVN Limited for Control Period

The detailed working of the economic analysis is provided in the Detailed Project Report.

As considerable time has elapsed since the approval of DPRs on 15.9.2010, the implementation schedule has now been revised and has been made realistic considering ongoing RMU of other projects of UJVN Ltd. The Financial Analysis provided herein is as per approved DPR prepared for RMU of the Project. It is considered that the Financial Analysis data given herein above shall hold good for the revised execution schedule and the project shall be viable.

The likely impact of the project on the environment has been carried and has been provided in the Detailed Project Report. Further a summary of the Environment Impact Analysis has been provided in annexure 11.

3.1.2.4 Status Update of Capital Expenditure:

DPR for RMU works has been prepared by M/s Lahmeyer International. The DPR has been approved by Board in its 56th BoD meeting held on 15-09- 2010. Qualification Criterion for Contractors for RMU of Chibro Power Station has been submitted to KfW and PFC for their NOC. Preparation of tender documents for RMU works is in progress and shall be submitted to PFC for their NOC.

3.1.3 Financing of Capital Expenditure:

3.1.3.1 The Project will be financed through a Debt: Equity ratio of 70:30. Out of Capex of Rs. 27.73 Crores planned during the control period, debt will be Rs. 19.41 Crores and equity contribution will be Rs. 8.32 Crores. Equity will be provided from budgetary support of GoU envisaged for UJVN Limited while debt will be provided

Business Plan of UJVN Limited for Control Period

by financial institutions like PFC, REC, NABARD, IREDA etc. Year-wise allocation of debt and equity for the control period is provided in the table below:

Table 35: Funding Pattern during the Control Period – Chibro Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Debt - - - 19.41 110.00 129.42 Equity - - - 8.32 47.14 55.46 Debt 0% 0% 0% 70% 70% 70% Equity 0% 0% 0% 30% 30% 30%

3.1.4 Capitalization Schedule:

3.1.4.1 The completion schedule for RMU works of various units of Chibro project is as under:

Unit No Start Date Completion Date

Unit I 1st November 2015 31st March 2017

Unit II 1st June 2017 31st March 2018

Unit III 1st June 2018 31st March 2019

Unit IV 1st June 2019 31st March 2020

3.1.4.2 Total capital expenditure of Rs. 184.88 Crores will get capitalized after the control period. Year-wise capitalization during the control period is provided in the table below:

Table 36: Capex & Capitalization during the Control Period – Chibro Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - - - 27.73 157.15 184.88 Capitalization - - - - 184.88 184.88

Business Plan of UJVN Limited for Control Period

3.2 Khodri Power Station (120 MW)

3.2.1 Background:

3.2.1.1 The Power Station is located downstream of the Chibro Power Station and was commissioned in the year 1984. The Power Station draws water through a tunnel 5.6 km long and 7.5 m in diameter, directly from the collection gallery of the Chibro Power Station. The surface Power Station comprising 4 units of 30 MW each with Francis Turbines of 43,600 HP output is located on the banks of Yamuna. The outlet of the water from the Power Station is in river Yamuna, upstream of the Dakpathar Barrage. Design head of the Power Station is 57.9 m.

3.2.1.2 The operation of Chibro Power Station and the Khodri Power Station is another engineering marvel. The tandem control scheme between Chibro and Khodri Power Stations is in operation since January, 1984 and is the first of its kind in the country which optimizes the utilization of water for generation besides maintaining the safety of both the stations in case of outages.

3.2.1.3 On 5th of March 2008, UJVN Limited entrusted the Consultant, Lahmeyer International GmbH., with a comprehensive study for the modernisation and upgradation of the station. The study is financed by the Kreditanstalt fur Wiederaufbau (KfW), Germany.

3.2.2 Capital Expenditure:

3.2.2.1 Capital Expenditure for RMU works is estimated at Rs. 169.63 Crores. Capital expenditure of Rs. 25.44 Crores is projected to be incurred during the control period. The year wise phasing of the capital expenditure during the control period is shown in the table below:

Table 37: Capital Expenditure during Control Period – Khodri Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - - - 25.44 144.19 169.63

Business Plan of UJVN Limited for Control Period

3.2.2.2 RMU Project

Primary purpose of RMU is life extension of the project apart from increase in generation. After RMU, generation will increase from 406 MU to 444 MU (as per DPR) subject to same water discharge. Details of the total project cost are provided in the table on the next page :

Business Plan of UJVN Limited for Control Period

Table 38: Capital Cost – Khodri Project KHODRI H. E. PROJECT (120 MW), UTTARAKHAND ABSTRACT OF COST S. No Description Amount (Rs. in Crores) 1 DIRECT CHARGES I - Works A - Preliminary 1.31 B - Land - C - Works - C1 - Civil Works - C2 - Hydrulic Steel Structures - J - Power Plant Civil Works J1 - Civil Works 1.95 J2 - Hydrulic Steel Structures 2.09 K - Buildings - M - Plantation - O - Miscellaneous 3.93 P - Maintenance During Construction 0.04 Q - Special Tools and Plants 0.10 R - Communication - S - Power Plant S1 - Mechanical Equipment 36.79 S2 - Electrical Equipment 89.97 X - Environment and Ecology 0.09 Y - Losses on Stock 0.01 TOTAL OF I - WORKS 136.27

II - Establishment 10.90 III - Tools and Plants 1.36 IV - Suspense - V- Receipt & Recoveries -0.02 TOTAL DIRECT CHARGES 148.51

2 INDIRECT CHARGES I - Capitalised Value of Abatement of Land Revenue - II - Audit & Accounts Charges 0.34 TOTAL INDIRECT CHARGES 0.34

TOTAL COST (Direct & Indirect Cost) 148.85

Escalation till start of M&U Measure 17.37 IDC 2.51 Commitment Fees 0.70 Up-front Fees - Guarantee Fees 0.19 Total 169.63

Business Plan of UJVN Limited for Control Period

3.2.2.3 Economic and Environment Impact Evaluation

The economic feasibility of the RM&U project for the Khodri Power Station was appraised using the following economic indicators:

The Economical Internal Rate of Return (EIRR) which represents the rate of return that equates the present value of costs with the present value of benefits; The Economic Net Present Value (ENPV) which is derived by discounting the net benefits; The benefit-cost-ratio which represents the ratio between the present value of benefits and the present value of costs.

An economic discount rate of ten percent (10%) was used in the appraisal of the economic feasibility. Results are summarised below:

RESULTS

Site Khodri Power Station

Economic Discount Rate 10.00%

EIRR (%) 23.29%

ENPV (Rs. Crores) 227.88

B/C Ratio 2.23

These results lead to the conclusion that the modernization and upgradation of the Khodri Power Station is an economically feasible project. This conclusion is drawn due to the following observations:

The EIRR is greater than the assumed economic discount rate of 10% The ENPV is greater than zero. The benefit-cost ratio is greater than one.

Business Plan of UJVN Limited for Control Period

The detailed working of the economic analysis is provided in the Detailed Project Report.

3.2.2.4 Status Update of Capital Expenditure:

DPR for RMU works has been prepared by M/s Lahmeyer International. The DPR has been approved by Board of UJVN Ltd. in its 56th BoD meeting held on 15-09-2010. Qualification Criterion for RMU of Khodri Power Station has been submitted to KfW and PFC for their NOC. Preparation of tender documents for RMU works is under progress and shall be submitted to PFC for their NOC.

3.2.3 Financing of Capital Expenditure:

3.2.3.1 The Project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of Rs. 25.44 Crores planned during the control period, Rs. 17.81 Crores will be funded through debt and Rs. 7.63 Crores through equity. Equity will be provided by GoU through budgetary support envisaged for UJVN Limited while debt will be

Business Plan of UJVN Limited for Control Period

provided financial institutions like PFC, REC, NABARD and IREDA etc. Year wise phasing of debt and equity for the control period is provided in the table below:

Table 39: Funding Pattern during the Control Period – Khodri Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Debt - - - 17.81 100.93 118.74 Equity - - - 7.63 43.26 50.89 Debt 0% 0% 0% 70% 70% 70% Equity 0% 0% 0% 30% 30% 30%

3.2.4 Capitalization Schedule:

3.2.4.1 The completion schedule for RMU works of various units of Khodri project is as under:

Unit No Start Date Completion Date

Unit I 1st November 2015 31st March 2017

Unit II 1st June 2017 31st March 2018

Unit III 1st June 2018 31st March 2019

Unit IV 1st June 2019 31st March 2020

3.2.4.2 Total capital expenditure of Rs. 169.63 Crores will get capitalized after the control period. Year-wise capitalization during the control period is provided in the table below:

Table 40: Capex & Capitalization during the Control Period – Khodri Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - - - 25.44 144.19 169.63 Capitalization - - - - 169.63 169.63

Business Plan of UJVN Limited for Control Period

3.3 Dhakrani Power Station (33.75 MW)

3.3.1 Background:

3.3.1.1 The Power Station is located on the downstream of the Dakpathar Barrage at a distance of 8 km on the Power Channel which takes off from the Barrage. The Power Station was commissioned in the year 1965.

3.3.1.2 The surface Power Station comprises of 3 units of 11.25 MW each with Kaplan Turbines of 14300 HP output. Water from Dhakrani Power Station feeds Dhalipur Power Station on its downstream side through the same Power Channel. Design head of the Power Station is 19.8 m.

3.3.1.3 On 5th of March 2008, UJVN Limited entrusted the Consultant, Lahmeyer International GmbH., with a comprehensive study for the modernisation and upgradation of the station. The study is financed by the Kreditanstalt fur Wiederaufbau (KfW), Germany.

3.3.2 Capital Expenditure:

3.3.2.1 Capital Expenditure for RMU works is estimated at Rs. 116.41 Crores.Capital expenditure of Rs. 40.74 Crores is projected to be incurred during the control period. The year wise phasing of the capital expenditure during the control period is shown in the table below:

Table 41: Capital Expenditure during the Control Period – Dhakrani Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - - 17.46 23.28 75.67 116.41

3.3.2.2 RMU Project

Financial tie-up for RM&U works of this power station has been done with KfW, Germany. General terms and conditions of funding from KfW are given in

Business Plan of UJVN Limited for Control Period

Annexure-12. UJVNL Limited had carried out a study through Uttarakhand Infrastructure Development Company for assessment of the viability of the funding from KfW as compared to funding from Indian Financial Institutions. UIDC had concluded that the funding from KfW would be cheaper than funding from Indian Financial Institution. Primary purpose of RMU is life extension of the project apart from increase in generation. After RMU, generation will increase from 161 MU to 184 MU (as per DPR) subject to same water discharge. Details of the total project cost are provided in the table on the next page :

Business Plan of UJVN Limited for Control Period

Table 42: Capital Cost – Dhakrani Project DHAKRANI H. E. PROJECT (33.75 MW), UTTARAKHAND ABSTRACT OF COST S. No Description Amount (Rs. in Crores) 1 DIRECT CHARGES I - Works A - Preliminary 0.89 B - Land - C - Works C1 - Civil Works 0.22 C2 - Hydrulic Steel Structures 6.01 J - Power Plant Civil Works J1 - Civil Works 1.74 J2 - Hydrulic Steel Structures 4.86 K - Buildings - M - Plantation - O - Miscellaneous 2.68 P - Maintenance During Construction 0.13 Q - Special Tools and Plants 0.10 R - Communication - S - Power Plant S1 - Mechanical Equipment 21.50 S2 - Electrical Equipment 54.75 X - Environment and Ecology 0.08 Y - Losses on Stock 0.03 TOTAL OF I - WORKS 93.00

II - Establishment 7.44 III - Tools and Plants 0.93 IV - Suspense - V- Receipt & Recoveries -0.02 TOTAL DIRECT CHARGES 101.35

2 INDIRECT CHARGES I - Capitalised Value of Abatement of Land Revenue - II - Audit & Accounts Charges 0.23 TOTAL INDIRECT CHARGES 0.23

TOTAL COST (Direct & Indirect Cost) 101.58

Escalation till start of M&U Measure 11.86 IDC 2.34 Commitment Fees 0.45 Up-front Fees - Guarantee Fees 0.18 Total 116.41

Business Plan of UJVN Limited for Control Period

3.3.2.3 Economic and Environment Evaluation

The economic feasibility of the RM&U project for the Dhakrani Power Station was appraised based on the following economic indicators:

An economic discount rate of ten percent (10%) was used in the appraisal of the economic feasibility. Results are summarised below:

RESULTS

Site Dhakrani Power Station

Economic Discount Rate 10.00%

EIRR (%) 25.67%

ENPV (Rs. Crores) 235.74

B/C Ratio 2.88

These results lead to the conclusion that the modernization and upgradation of the Dhakrani Power Station is an economically feasible project. The conclusion is drawn due to the following observations:

The EIRR is greater than the assumed economic discount rate of 10% The ENPV is greater than zero. The benefit-cost ratio is greater than one.

Business Plan of UJVN Limited for Control Period

The detailed working of the economic analysis is provided in Detailed Project Report.

3.3.2.4 Status Update of Capital Expenditure:

DPR for RMU works has been prepared by M/s Lahmeyer International. The DPR has been approved by Board of UJVN Limited in its 56th BoD meeting held on 15-09-2010. On the basis of NOC from KfW on the Qualification Criterion for 3X11.25 MW Dhakrani Power Station, Qualification Criteria for the project has been approved by the Chairman, UJVN Limited. Tender for the project has been published upon receipt of NoC on Short Notice inviting bids and tender documents (International Competitive Bidding) from KfW and PFC. Contract for RMU of Dhakrani Power Station is likely to be awarded by 31-06- 2013.

3.3.3 Financing of Capital Expenditure:

3.3.3.1 The Project will be financed with the Debt: Equity ratio of 80:20. Out of Capex of Rs. 40.74 Crores planned during the control period, debt will be Rs. 32.59 Crores

Business Plan of UJVN Limited for Control Period

and equity contribution will be Rs. 8.15 Crores. Equity will be provided from budgetary support of GoU envisaged for UJVN Limited while debt will be provided by KfW & PFC. Year-wise allocation of debt and equity for the control period is provided in the table below:

Table 43: Funding Pattern during the Control Period – Dhakrani Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Debt - - 13.97 18.63 60.53 93.13 Equity - - 3.49 4.66 15.13 23.28 Debt 0% 0% 80% 80% 80% 80% Equity 0% 0% 20% 20% 20% 20%

3.3.4 Capitalization Schedule:

3.3.4.1 The completion schedule for RMU works of various units of Dhakrani project is as under:

Unit No Start Date Completion Date

Unit I 1st October 2014 30th June 2015

Unit II 1st October 2015 30th June 2016

Unit III 1st October 2016 30th June 2017

3.3.4.2 Out of total capital expenditure of Rs. 40.74 Crores, Rs 38.80 Crores will get capitalized during the control period. Year-wise capitalization during the control period is provided in the table below:

Table 44: Capex & Capitalization during the Control Period – Dhakrani Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - - 17.46 23.28 75.67 116.41 Capitalization - - - 38.80 77.61 116.41

Business Plan of UJVN Limited for Control Period

3.4 Dhalipur Power Station (51 MW)

3.4.1 Background:

3.4.1.1 The Power Station is located on the downstream of the Dhakrani Power Station at a distance of 4 km on the Power Channel which takes off from the Dakpathar Barrage. The Power Station was commissioned in the year 1965.

3.4.1.2 The surface Power Station comprises 3 units of 17 MW each with Francis Turbine of 24,000 HP output. The water from the Tail Race of the Power Station joins Asan River at Asan Barrage. Design head of the Power Station is 30.48 m.

3.4.1.3 On 5th of March 2008, UJVN Limited entrusted the Consultant, Lahmeyer International GmbH., with a comprehensive study for the modernisation and upgradation of the station. The study is financed by the Kreditanstalt fur Wiederaufbau (KfW), Germany.

3.4.2 Capital Expenditure:

3.4.2.1 Capital Expenditure for RMU works is estimated at Rs. 116.81 Crores. Capital expenditure of Rs. 40.88 Crores is projected to be incurred during the control period. The year wise phasing of the capital expenditure during the control period is shown in the table below:

Table 45: Capital Expenditure during the Control Period – Dhalipur Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - - 17.52 23.36 75.93 116.81

3.4.2.2 RMU Project

Financial tie-up for RM&U works of this power station has been done with KfW, Germany. General terms and conditions of funding from KfW are given in Annexure-12. UJVNL Limited had carried out a study through Uttarakhand

Business Plan of UJVN Limited for Control Period

Infrastructure Development Company for assessment of the viability of the funding from KfW as compared to funding from Indian Financial Institutions. UIDC had concluded that the funding from KfW would be cheaper than funding from Indian Financial Institution. Primary purpose of RMU is life extension of the project apart from increase in generation. After RMU, generation will increase from 240 MU to 276 MU (as per DPR) subject to same water discharge. Details of the total project cost are provided in the table on the next page :

Business Plan of UJVN Limited for Control Period

Table 46: Capital Cost – Dhalipur Project DHALIPUR H. E. PROJECT (51 MW), UTTARAKHAND ABSTRACT OF COST S. No Description Amount (Rs. in Crores) 1 DIRECT CHARGES I - Works A - Preliminary 0.90 B - Land - C - Works - C1 - Civil Works - C2 - Hydrulic Steel Structures - J - Power Plant Civil Works J1 - Civil Works 1.23 J2 - Hydrulic Steel Structures 4.76 K - Buildings - M - Plantation - O - Miscellaneous 2.69 P - Maintenance During Construction 0.06 Q - Special Tools and Plants 0.10 R - Communication - S - Power Plant S1 - Mechanical Equipment 30.12 S2 - Electrical Equipment 53.47 X - Environment and Ecology 0.08 Y - Losses on Stock 0.01 TOTAL OF I - WORKS 93.43

II - Establishment 7.47 III - Tools and Plants 0.93 IV - Suspense - V- Receipt & Recoveries -0.02 TOTAL DIRECT CHARGES 101.82

2 INDIRECT CHARGES I - Capitalised Value of Abatement of Land Revenue - II - Audit & Accounts Charges 0.23 TOTAL INDIRECT CHARGES 0.23

TOTAL COST (Direct & Indirect Cost) 102.05

Escalation till start of M&U Measure 11.91 IDC 2.20 Commitment Fees 0.48 Up-front Fees - Guarantee Fees 0.16 Total 116.81

Business Plan of UJVN Limited for Control Period

3.4.2.3 Economic and Environment Impact Evaluation

The economic feasibility of the M&U project for the Dhalipur Power Station was appraised based on the following economic indicators:

An economic discount rate of ten percent (10%) was used in the appraisal of the economic feasibility. Results are summarised below:

RESULTS

Site Dhalipur Power Station

Economic Discount Rate 10.00%

EIRR (%) 24.96%

ENPV (Rs. Crores) 252.05

B/C Ratio 2.97

These results lead to the conclusion that the modernization and upgradation of the Dhalipur Power Station is an economically feasible project. The conclusion is drawn due to the following observations:

The EIRR is greater than the assumed economic discount rate of 10% The ENPV is greater than zero. The benefit-cost ratio is greater than one.

Business Plan of UJVN Limited for Control Period

The detailed working of the economic analysis is provided in the Detailed Project Report.

3.4.2.4 Status Update of Capital Expenditure:

DPR for RMU works has been prepared by M/s Lahmeyer International. The DPR has been approved by Board of UJVN Limited in its 56th BoD meeting held on 15-09-2010. On the basis of NOC from KfW on the Qualification Criterion for 3X17 MW, Dhalipur Power Station, Qualification Criteria for the project has been approved by the Chairman, UJVN Limited. Tender for the project has been published upon receipt on NoC on Short Notice inviting bids and tender documents (International Competitive Bidding) from KfW and PFC. Contract for RMU of Dhalipur Power Station is likely to be awarded by 31-06- 2013.

3.4.3 Financing of Capital Expenditure:

3.4.3.1 The Project will be financed with the Debt: Equity ratio of 80:20. Out of Capex of Rs. 40.88 Crores planned during the control period, debt will be Rs. 32.71 Crores

Business Plan of UJVN Limited for Control Period

and equity contribution will be Rs. 8.17 Crores. Equity will be provided from budgetary support of GoU envisaged for UJVN Limited while debt will be provided by KfW & PFC. Year-wise allocation of debt and equity for the control period is provided in the table below:

Table 47: Funding Pattern during Control Period – Dhalipur Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Debt - - 14.02 18.69 60.74 93.45 Equity - - 3.50 4.67 15.19 23.36 Debt 0% 0% 80% 80% 80% 80% Equity 0% 0% 20% 20% 20% 20%

3.4.4 Capitalization Schedule:

3.4.4.1 The completion schedule for RMU works of various units of Dhalipur project is as under:

Unit No Start Date Completion Date

Unit I 1st October 2014 30th June2015

Unit II 1st October 2015 30th June 2016

Unit III 1st October 2016 30th June 2017

3.4.4.2 Out of total capital expenditure of Rs. 40.88 Crores during the control period, Rs. 38.94 Crores will get capitalized during the control period. Year-wise capitalization during the control period is provided in the table below:

Table 48: Capex & Capitalization during the Control Period – Dhalipur Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - - 17.52 23.36 75.93 116.81 Capitalization - - - 38.94 77.87 116.81

Business Plan of UJVN Limited for Control Period

3.5 Kulhal Power Station (30 MW)

3.5.1 Background:

3.5.1.1 The Power Station is located on the downstream of the Asan Barrage at a distance of 4.5 km on the Power Channel which takes off from the Asan Barrage. The Power Station was commissioned in the year 1975.

3.5.1.2 The surface Power Station comprising three units of 10 MW each with Kaplan turbine is located on the Power Channel. The water from the tail race flows towards Khara Power Station in UP. Design Head of the Power Station is 18 m.

3.5.1.3 On 5th of March 2008, UJVN Limited entrusted the Consultant, Lahmeyer International GmbH., with a comprehensive study for the modernisation and upgradation of the station. The study is financed by the Kreditanstalt fur Wiederaufbau (KfW), Germany.

3.5.2 Capital Expenditure:

3.5.2.1 Capital Expenditure for RMU works is estimated at Rs. 118.72 Crores. Capital expenditure of Rs. 41.55 Crores is projected to be incurred during the control period. The year wise phasing of the capital expenditure during the control period is shown in the table below:

Table 49: Capital Expenditure during the Control Period – Kulhal Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - - 17.81 23.74 77.17 118.72

3.5.2.2 RMU Project

Financial tie-up for RM&U works of six stations has been done with KfW, Germany. General terms and conditions of funding from KfW are given in Annexure-12. UJVNL Limited had carried out a study through Uttarakhand

Business Plan of UJVN Limited for Control Period

Infrastructure Development Company for assessment of the viability of the funding from KfW as compared to funding from Indian Financial Institutions. UIDC had concluded that the funding from KfW would be cheaper than funding from Indian Financial Institution. Primary purpose of RMU is life extension of the project apart from increase in generation. After RMU, generation will increase from 145 MU to 183 MU (as per DPR) subject to same water discharge. Detail of the total cost is provided in the table on the next page :

Business Plan of UJVN Limited for Control Period

Table 50: Capital Cost – Kulhal Project KULHAL H. E. PROJECT (30 MW), UTTARAKHAND ABSTRACT OF COST S. No Description Amount (Rs. in Crores) 1 DIRECT CHARGES I - Works A - Preliminary 0.91 B - Land - C - Works - C1 - Civil Works 0.22 C2 - Hydrulic Steel Structures 4.97 J - Power Plant Civil Works J1 - Civil Works 1.41 J2 - Hydrulic Steel Structures 4.66 K - Buildings - M - Plantation - O - Miscellaneous 2.73 P - Maintenance During Construction 0.11 Q - Special Tools and Plants 0.10 R - Communication - S - Power Plant S1 - Mechanical Equipment 19.19 S2 - Electrical Equipment 60.43 X - Environment and Ecology 0.08 Y - Losses on Stock 0.03 TOTAL OF I - WORKS 94.85

II - Establishment 7.59 III - Tools and Plants 0.95 IV - Suspense - V- Receipt & Recoveries -0.02 TOTAL DIRECT CHARGES 103.37

2 INDIRECT CHARGES I - Capitalised Value of Abatement of Land Revenue - II - Audit & Accounts Charges 0.24 TOTAL INDIRECT CHARGES 0.24

TOTAL COST (Direct & Indirect Cost) 103.61

Escalation till start of M&U Measure 12.10 IDC 2.38 Commitment Fees 0.46 Up-front Fees - Guarantee Fees 0.18 Total 118.72

Business Plan of UJVN Limited for Control Period

3.5.2.3 Economic and Environment Impact Evaluation

The economic feasibility of the M&U project for the Kulhal Power Station was appraised based on the following economic indicators:

An economic discount rate of ten percent (10%) was used in the appraisal of the economic feasibility. Results are summarised below:

RESULTS

Site Kulhal Power Station

Economic Discount Rate 10.00%

EIRR (%) 20.57%

ENPV (Rs. Crores) 143.86

B/C Ratio 2.12

These results lead to the conclusion that the modernization and upgradation of the Kulhal Power Station is an economically feasible project. The conclusion is drawn due to the following observations:

The EIRR is greater than the assumed economic discount rate of 10% The ENPV is greater than zero. The benefit-cost ratio is greater than one.

Business Plan of UJVN Limited for Control Period

The detailed working of the economic analysis is provided in the Detailed Project Report.

3.5.2.4 Status Update of Capital Expenditure:

DPR for RMU works has been prepared by M/s Lahmeyer International. The DPR has been approved by Board of UJVN Limited in its 56th BoD meeting held on 15-09-2010. Short Notice inviting bids (International Competitive Bidding) and tender documents for the project has been published in newspapers on 25.03.2011. The tender is under evaluation. Contract for RMU of Kulhal Power Station is likely to be awarded by 30th June 2013..

3.5.3 Financing of Capital Expenditure:

3.5.3.1 The Project will be financed with the Debt: Equity ratio of 80:20. Out of Capex of Rs. 41.55 Crores planned during the control period, debt will be Rs. 33.24 Crores and equity contribution will be Rs. 8.31 Crores. Equity will be provided from budgetary support of GoU envisaged for UJVN Limited while debt will be provided

Business Plan of UJVN Limited for Control Period

by KfW & PFC. Year-wise allocation of debt and equity for the control period is provided in the table below:

Table 51: Funding Pattern during the Control Period – Kulhal Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Debt - - 14.25 19.00 61.73 94.98 Equity - - 3.56 4.75 15.43 23.74 Debt 0% 0% 80% 80% 80% 80% Equity 0% 0% 20% 20% 20% 20%

3.5.4 Capitalization Schedule:

3.5.4.1 The completion schedule for RMU works of various units of Kulhal project is as under:

Unit No Start Date Completion Date

Unit I 1st October 2014 30th June 2015

Unit II 1st October 2015 30th June 2016

Unit III 1st October 2016 30th June 2017

3.5.4.2 Out of total capital expenditure of Rs. 41.55 Crores, Rs 39.57 Crores will get capitalized during the control period. Year-wise capitalization during the control period is provided in the table below:

Table 52: Capex & Capitalization during the Control Period – Kulhal Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - - 17.81 23.74 77.17 118.72 Capitalization - - - 39.57 79.15 118.72

Business Plan of UJVN Limited for Control Period

3.6 Tiloth Power Station (90 MW)

3.6.1 Background:

3.6.1.1 Maneri Bhali Stage-I Project harnesses power potential of river ‘Bhagirathi’ between Maneri and Tiloth in district Uttarkashi for generation of electrical power. The Power Station was commissioned in the year 1984.

3.6.1.2 The Power Station consists of three generating units of 30 MW. Each Unit has vertical shaft, suspension type Hydro-Generator coupled to Francis type hydro turbines supplied by M/s. BHEL. The Hydraulic system of the Power Station consists of a diversion dam at Maneri and about 6.5 Km long, 6 m dia pressure tunnel, surge tank at the end of tunnel and a single penstock controlled by a gate at surge tank, trifurcating into three units penstock near the upstream of Power Station building, each controlled by a spherical valve of 1.8 m dia operating under a head of about 180 m. Each unit is connected to the tail race channel through the draft tube controlled by a draft tube gate. The tail race is a short open channel connecting to river Bhagirathi.

3.6.1.3 On 5th of March 2008, UJVN Limited entrusted the Consultant, Lahmeyer International GmbH., with a comprehensive study for the modernisation and upgradation of the station. The study is financed by the Kreditanstalt fur Wiederaufbau (KfW), Germany.

3.6.2 Capital Expenditure:

3.6.2.1 Capital Expenditure for RMU works is estimated at Rs. 126.23 Crores. Capital expenditure of Rs. 88.36 Crores is projected to be incurred during the control period. The year wise phasing of the capital expenditure during the control period is shown in the table on the next page :

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Table 53: Capital Expenditure during the Control Period – Tiloth Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - 18.93 25.25 44.18 37.87 126.23

3.6.2.2 RMU Project

Primary purpose of RMU is life extension of the project apart from increase in generation. After RMU, generation will increase from 446 MU to 484 MU (as per DPR) subject to same water discharge. Details of the total project cost are provided in the table on the next page :

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Table 54: Capital Cost – Tiloth Project TILOTH H. E. PROJECT (90 MW), UTTARAKHAND ABSTRACT OF COST S. No Description Amount (Rs. in Crores) 1 DIRECT CHARGES I - Works A - Preliminary 0.97 B - Land - C - Works C1 - Civil Works 3.04 C2 - Hydrulic Steel Structures 2.19 J - Power Plant Civil Works J1 - Civil Works 2.42 J2 - Hydrulic Steel Structures 5.08 K - Buildings - M - Plantation - O - Miscellaneous 2.90 P - Maintenance During Construction 0.13 Q - Special Tools and Plants 0.10 R - Communication - S - Power Plant S1 - Mechanical Equipment 17.96 S2 - Electrical Equipment 65.86 X - Environment and Ecology 0.18 Y - Losses on Stock 0.03 TOTAL OF I - WORKS 100.85

II - Establishment 8.07 III - Tools and Plants 1.01 IV - Suspense - V- Receipt & Recoveries - TOTAL DIRECT CHARGES 109.92

2 INDIRECT CHARGES I - Capitalised Value of Abatement of Land Revenue - II - Audit & Accounts Charges 0.25 TOTAL INDIRECT CHARGES 0.25

TOTAL COST (Direct & Indirect Cost) 110.18

Escalation till start of M&U Measure 12.84 IDC 2.53 Commitment Fees 0.49 Up-front Fees - Guarantee Fees 0.19 Total 126.23

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Business Plan of UJVN Limited for Control Period

3.6.2.3 Economic and Environment Impact Evaluation:

The economic feasibility of the RM&U project for the Tiloth Power Station was appraised based on the following economic indicators:

An economic discount rate of ten percent (10%) was used in the appraisal of the economic feasibility. Results are summarised below:

RESULTS

Site Tiloth Power Station

Economic Discount Rate 10.00%

EIRR (%) 29.28%

ENPV (Rs. Crores) 262.06

B/C Ratio 2.87

These results lead to the conclusion that the modernization and upgradation of the Tiloth Power Station represents an economically feasible project. The conclusion is drawn due to the following observations:

The EIRR is greater than the assumed economic discount rate of 10% The ENPV is greater than zero. The benefit-cost ratio is greater than one.

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The detailed working of the economic analysis is provided in the Detailed Project Report.

3.6.2.4 Status Update of Capital Expenditure:

DPR for RMU works has been prepared by M/s Lahmeyer International. The DPR has been approved by Board of UJVN Limited in its 56th BoD meeting held on 15-09-2010. Qualification Criterion and tender documents for RM&U of 3X30 MW Tiloth Power Station are under preparation and shall be submitted PFC for their NOC.

3.6.3 Financing of Capital Expenditure:

3.6.3.1 The Project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of Rs. 88.36 Crores planned during the control period, debt will be Rs. 61.85 Crores and equity contribution will be Rs. 26.51 Crores. Equity will be provided from budgetary support of GoU envisaged for UJVN Limited while debt will be provided

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by financial institution like PFC, REC, NABARD and IREDA etc. Year-wise allocation of debt and equity for the control period is provided in the table below:

Table 55: Funding Pattern during the Control Period – Tiloth Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Debt - 13.25 17.67 30.93 26.51 88.36 Equity - 5.68 7.57 13.25 11.36 37.87 Debt 0% 70% 70% 70% 70% 70% Equity 0% 30% 30% 30% 30% 30%

3.6.4 Capitalization Schedule:

3.6.4.1 The completion schedule for RMU works of various units of Tiloth project is as under:

Unit No Start Date Completion Date

Unit I 1st November 2013 31st March 2015

Unit II 1st June 2015 31st March 2016

Unit III 1st June 2016 31st March 2017

3.6.4.2 Out of total capital expenditure of Rs. 88.36 Crores, Rs. 84.15 Crores will get capitalized during the control period. Year-wise capitalization during the control period is provided in the table below:

Table 56: Capex & Capitalization during the Control Period – Tiloth Project Rs.Crores upto FY 2013- FY 2014- FY 2015- after Year 31.03.2013 14 15 16 31.03.2016 Total Capital Expenditure - 18.93 25.25 44.18 37.87 126.23 Capitalization - - 42.08 42.08 42.08 126.23

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Business Plan of UJVN Limited for Control Period

3.7 Chilla Power Station (144 MW)

3.7.1 Background:

3.7.1.1 The Power Station is a Run-of-River scheme on river Ganga located upstream of the holy city Hardwar and was commissioned in the year 1980.

3.7.1.2 The Power Station has four units of 36 MW each. The four Kaplan Vertical Shaft Turbines operate at a head of 32.5 m. Water of River Ganga from Pashulok Barrage is diverted through a Power Channel to feed the turbines of Chilla Power Station.

3.7.1.3 Government of Uttarakhand (GoU) entered into an agreement with CCC, Canada for Chilla Hydroelectric Project Up-gradation Program.

3.7.2 Capital Expenditure:

3.7.2.1 Capital Expenditure for RMU works is Rs. 337.00 Crores. Initially funding was to be provided by EDC line of credit but an agreement could not be reached between borrower and GoU, now funding is likely to be tied up with Financial Institution like PFC, REC, IREDA, NABARD etc. Capital expenditure of Rs. 161.76 Crores is projected to be incurred during the control period. The year wise phasing of the capital expenditure during the control period is shown in the table below:

Table 57: Capital Expenditure during the Control Period – Chilla Project Rs. Crores upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total Capital Expenditure - - 33.70 128.06 175.24 337.00

3.7.2.2 RMU Project

Primary purpose of RMU is life extension of the project apart from increase in generation. After RMU, generation will increase from 684 MU (Pre-Tehri scenario) to 1074 MU (after commissioning of Tehri Hydroelectric Project).. Capacity of machine will enhance from present 36 MW to 43.2 MW and install capacity of

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plant will increase from 144 MW to 172.8 MW on account of RMU. Detail of the total cost is provided in the table on the next page :

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Table 58: Capital Cost – Chilla Project CHILLA H. E. PROJECT (144 MW), UTTARAKHAND ABSTRACT OF COST S. No Description Amount (Rs. in Crores) 1 DIRECT CHARGES I - Works A - Preliminary - B - Land - C - Works C1 - Civil Works - C2 - Hydrulic Steel Structures - J - Power Plant Civil Works J1 - Civil Works 23.96 J2 - Hydrulic Steel Structures 6.37 K - Buildings - M - Plantation - O - Miscellaneous - P - Maintenance During Construction - Q - Special Tools and Plants 4.92 R - Communication - S - Power Plant S1 - Mechanical Equipment 134.83 S2 - Electrical Equipment 129.92 X - Environment and Ecology - Y - Losses on Stock - TOTAL OF I - WORKS 300.00

II - Establishment III - Tools and Plants IV - Suspense - V- Receipt & Recoveries - TOTAL DIRECT CHARGES 300.00

2 INDIRECT CHARGES I - Capitalised Value of Abatement of Land Revenue - II - Audit & Accounts Charges - TOTAL INDIRECT CHARGES -

TOTAL COST (Direct & Indirect Cost) 300.00

Escalation till start of M&U Measure IDC 37.00 Commitment Fees - Up-front Fees - Guarantee Fees - Total 337.00

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Business Plan of UJVN Limited for Control Period

3.7.2.3 Economic and Environment Impact Evaluation:

The economic feasibility of the RM&U project for the Chilla Power Station was appraised based on the following economic indicators:

An economic discount rate of ten percent (10%) was used in the appraisal of the economic feasibility. Results are summarised below:

RESULTS

Site Chilla Power Station

Economic Discount Rate 10.00%

EIRR (%) 24.74%

ENPV (Rs. Crores) 528.37

B/C Ratio 2.86

These results lead to the conclusion that the modernization and upgrading of the Chilla Power Station represents an economically feasible project. The conclusion is drawn due to the following observations:

The EIRR is greater than the assumed economic discount rate of 10% The ENPV is greater than zero. The benefit-cost ratio is greater than one.

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The detailed working of the economic analysis is provided in the Detailed Project Report.

The likely impact of the project on the environment has been carried and has been provided in the Detailed Project Report.

3.7.2.4 Status Update of Capital Expenditure:

DPR for RMU works has been prepared by M/s CCC, Canada/ SNC Lavalin Inc. Amendment to Agreement No. 2 for revised scope and Supplementary Agreement for Phase 2 has been examined and a letter has been sent to GoU for entering into agreement for Phase-2 (Execution Phase). Comprehensive note regarding Phase-2 agreement was sent to GoU in October 2010 for approval. Some queries were received from GoU regarding Phase-2 Agreement. Replies have been submitted to GoU in March 2011 and decision from GoU is awaited. Due to delay in execution of the project, letter recommending the termination of contract with CCC has been sent to GOU in December 2012.

3.7.3 Financing of Capital Expenditure:

3.7.3.1 The project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of Rs. 161.76 Crores planned during the control period, debt will be Rs. 113.23 Crores and equity contribution will be Rs. 48.53 Crores. Equity will be provided from budgetary support of GoU envisaged for UJVN Limited while debt is required to be arranged from financial institutions like PFC, REC, NABARD and IREDA etc. Year-wise allocation of debt and equity for the control period is provided in the table below:

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Table 59: Funding Pattern during the Control Period – Chilla Project Rs. Crores Year upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total Debt - - 23.59 89.64 122.67 235.90 Equity - - 10.11 38.42 52.57 101.10 Debt 0% 0% 70% 70% 70% 70% Equity 0% 0% 30% 30% 30% 30%

3.7.4 Capitalization Schedule:

3.7.4.1 The completion schedule for RMU works of various units of Chilla project is as under:

Unit No Start Date Completion Date

Unit I 1st November 2014 31st March 2016

Unit II 1st June 2016 31st March 2017

Unit III 1st June 2017 31st March 2018

Unit IV 1st June 2018 31st March 2019

3.7.4.2 Total Capex will get capitalized after the control period. Year-wise capitalization during the control period is provided in the table below:

Table 60: Capex & Capitalization during the Control Period – Chilla Project Rs. Crores Year upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total Capital Expenditure - - 33.70 128.06 175.24 337.00 Capitalization - - - - 337.00 337.00

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Business Plan of UJVN Limited for Control Period

3.8 Khatima Power Station (41.40 MW)

3.8.1 Background:

3.8.1.1 The Power Station is located on the downstream of the Banbasa Barrage over River Sharda at a distance of 16 km on the irrigation canal which takes off from the Barrage. The Power Station was commissioned in the year 1955 & 1956. The surface Power Station comprising 3 units of 13.8 MW each with Kaplan turbines of 19200 HP output is located on the unlined irrigation canal. The water is utilized for the irrigation purpose in the command area of the canal. Design Head of the Power Station is 17.98 m.

3.8.1.2 The Khatima Power Station is a low head station with a design discharge of 269 cum. The discharge in the canal is regulated by Irrigation Department of Uttar Pradesh depending upon the irrigation requirement in the command area of the Irrigation canal and is also limited to the capacity of the escape channel downstream of the Power Station in case there is no demand.

3.8.2 Capital Expenditure:

3.8.2.1 Capital Expenditure for RMU works is estimated at Rs. 220.44 Crores. Capital expenditure of Rs. 171.04 Crores is projected to be incurred during the control period. The year wise phasing of the capital expenditure during the control period is shown in the table below:

Table 61: Capital Expenditure during the Control Period – Khatima Project Rs. Crores upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total Capital Expenditure 49.40 84.28 60.82 25.94 - 220.44

3.8.2.2 RMU Project

Primary purpose of RMU is life extension of the project apart from increase in generation. After RMU, generation will increase from 149.03 MU to 235 MU (as

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Business Plan of UJVN Limited for Control Period

per DPR) subject to same water discharge. Details of the total project cost are provided in the table on the next page :

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Table 62: Capital Cost – Khatima Project KHATIMA H. E. PROJECT (41.40 MW), UTTARAKHAND ABSTRACT OF COST S. No Description Amount (Rs. in Crores) 1 DIRECT CHARGES I - Works A - Preliminary 0.95 B - Land - C - Works C1 - Civil Works - C2 - Hydrulic Steel Structures - J - Power Plant Civil Works J1 - Civil Works 30.22 J2 - Hydrulic Steel Structures 14.39 K - Buildings - M - Plantation - O - Miscellaneous - P - Maintenance During Construction 0.43 Q - Special Tools and Plants - R - Communication - S - Power Plant S1 - Mechanical Equipment 129.50 S2 - Electrical Equipment X - Environment and Ecology - Y - Losses on Stock 0.07 TOTAL OF I - WORKS 175.56

II - Establishment 7.02 III - Tools and Plants 1.75 IV - Suspense - V- Receipt & Recoveries -0.79 TOTAL DIRECT CHARGES 183.54

2 INDIRECT CHARGES I - Capitalised Value of Abatement of Land Revenue - II - Audit & Accounts Charges 1.75 TOTAL INDIRECT CHARGES 1.75

TOTAL COST (Direct & Indirect Cost) 185.30

Escalation till start of M&U Measure - IDC 35.14 Commitment Fees - Up-front Fees - Guarantee Fees - Total 220.44

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3.8.2.3 Economic and Environmental Impact Evaluation:

The economic feasibility of the RM&U project for the Khatima Power Station was appraised in the Detailed Project Report prepared in-house which has projected cost of Rs. 256 Crores. Based on the tender invited by UJVN Limited, the revised cost is coming out to Rs. 220.44 Crores. Economic evaluation based on the DPR cost is shown below for reference. Economic evaluation is done based on the following economic indicators:

An economic discount rate of ten percent (10%) was used in the appraisal of the economic feasibility. Results are summarised below:

RESULTS

Site Khatima Power Station

Economic Discount Rate 10.00%

EIRR (%) 11.32%

ENPV (Rs. Crores) 34.22

B/C Ratio 1.18

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Business Plan of UJVN Limited for Control Period

These results lead to the conclusion that the modernization and upgrading of the Khatima Power Station is an economically feasible project. The conclusion is drawn due to the following observations:

The EIRR is greater than the assumed economic discount rate of 10% The ENPV is greater than zero. The benefit-cost ratio is greater than one.

The detailed working of the economic analysis is provided in the Detailed Project Report.

The likely impact of the project on the environment has been carried and has been provided in the Detailed Project Report.

3.8.2.4 Status Update of Capital Expenditure:

DPR for RM&U of Khatima Power Station has been approved by the BoD of UJVN Limited in its 56th Board meeting held on 15.09.2010. NIT for E&M and Hydro mechanical works has been published in newspapers on 25.02.2011. Part-I was opened on 21.07.2011 and Price bid (part-II) has been opened on 21.10.2011. Letter of award has been issued on 12.12.2011 to JV of M/s Alstom (India) Pvt., Vadodara and M/s PES Engineers Pvt. Limited, Hyderabad and contract has been signed on 03.01.2012. RMU of Unit-1 started on 1st October 2012

3.8.3 Financing of Capital Expenditure:

3.8.3.1 The Project is being financed with the Debt: Equity ratio of 70:30. Out of Capex of Rs. 171.04 Crores planned during the control period, debt will be Rs. 119.73 Crores

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and equity contribution will be Rs. 51.31 Crores. Equity will be provided from budgetary support of GoU envisaged for UJVN Limited while loan has been tied up with Power Finance Corporation. Copy of loan agreement is provided in Annexure 14. Year-wise allocation of debt and equity for the control period is provided in the table below:

Table 63: Funding Pattern during the Control Period – Khatima Project Rs. Crores Year upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total Debt 34.58 58.99 42.57 18.16 - 154.31 Equity 14.82 25.28 18.24 7.78 - 66.13 Debt 70% 70% 70% 70% 0% 70% Equity 30% 30% 30% 30% 0% 30%

3.8.4 Capitalization Schedule:

3.8.4.1 The completion schedule for RMU works of various units of Khatima project is as under:

Unit No Start Date Completion Date

Unit I 1st October 2012 31st March 2014

Unit II 1st April 2014 31st January 2015

Unit III 1st January 2015 31st October 2015

3.8.4.2 Total capital expenditure of Rs. 220.44 Crores will get capitalized during the control period. Year-wise capitalization during the control period is provided in the table below:

Table 64: Capex & Capitalization during the Control Period – Khatima Project Rs. Crores Year upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total Capital Expenditure 49.40 84.28 60.82 25.94 - 220.44 Capitalization - - 146.96 73.48 - 220.44

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3.9 Ramganga Power Station (198 MW)

3.9.1 Background:

3.9.1.1 The Power Station is a Reservoir based scheme on river Ramganga located near the famous Jim Corbett Park in district Pauri Garwhal and utilizes the water dammed up for irrigation purpose. The Project was commissioned in the year 1975. The water in the irrigation channel is regulated by Irrigation Department of Uttar Pradesh. The generation from Power Station is dependent on the rains in the catchment area and also on the drawl of water for irrigation purpose in the command area of the canal. The surface Power Station is located at the toe of the dam and houses 3 units of 66 MW each with Francis turbines of 92400 HP. Design Head of the Power Station is 84.4 m.

3.9.1.2 The Ramganga Power Station is a medium head scheme with a design discharge of 285 cum. The Project has unique challenges in operation due to restriction imposed on the release of water in the water conductor system by Irrigation Department of Uttar Pradesh which is dependent on the demand of water in the command area of the canal based on the irrigation requirement. The generation in the station takes place after the monsoon season when the demand for irrigation picks up.

3.9.1.3 UJVN Limited has done comprehensive study in-house for the modernisation and upgradation of the station.

3.9.2 Capital Expenditure:

3.9.2.1 Capital Expenditure for RMU works is estimated at Rs. 455.22 Crores. Capital expenditure of Rs. 240.25 Crores is projected to be incurred during the control period. The year wise phasing of the capital expenditure during the control period is shown in the table on the next page :

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Table 65: Capital Expenditure during the Control Period – Ramganga Project Rs. Crores upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total Capital Expenditure - 39.01 81.44 119.80 214.97 455.22

3.9.2.2 RMU Project

Primary purpose of RMU is life extension of the project apart from increase in generation. After RMU, generation will increase from 283 MU to 450 MU (as per DPR) corresponding to 363/364m dam level at the end of filling period subject to releases by UP irrigation department. Detail of the total cost is provided in the table on the next page :

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Table 66: Capital Cost – Ramganga Project RAMGANGA H. E. PROJECT (198 MW), UTTARAKHAND ABSTRACT OF COST S. No Description Amount (Rs. in Crores) 1 DIRECT CHARGES I - Works A - Preliminary 0.77 B - Land - C - Works C1 - Civil Works 1.70 C2 - Hydrulic Steel Structures - J - Power Plant Civil Works J1 - Civil Works 3.61 J2 - Hydrulic Steel Structures 2.33 K - Buildings - M - Plantation - O - Miscellaneous - P - Maintenance During Construction - Q - Special Tools and Plants - R - Communication - S - Power Plant S1 - Mechanical Equipment 150.78 S2 - Electrical Equipment 181.27 X - Environment and Ecology - Y - Losses on Stock 0.01 TOTAL OF I - WORKS 340.47

II - Establishment 13.59 III - Tools and Plants 3.40 IV - Suspense - V- Receipt & Recoveries -0.03 TOTAL DIRECT CHARGES 357.43

2 INDIRECT CHARGES I - Capitalised Value of Abatement of Land Revenue - II - Audit & Accounts Charges 3.40 TOTAL INDIRECT CHARGES 3.40

TOTAL COST (Direct & Indirect Cost) 360.83

Escalation till start of M&U Measure - IDC 94.38 Commitment Fees - Up-front Fees - Guarantee Fees - Total 455.22

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3.9.2.3 Economic and Environmental Impact Evaluation:

The economic feasibility of the RM&U project for the Ramganga Power Station was appraised based on the following economic indicators:

An economic discount rate of ten percent (10%) was used in the appraisal of the economic feasibility. Results are summarised below:

RESULTS

Site Ramganga Power Station

Economic Discount Rate 10.00%

EIRR (%) 12.97%

ENPV (Rs. Crores) 82.92

B/C Ratio 1.41

These results lead to the conclusion that the modernization and upgradation of the Ramganga Power Station represents an economically feasible project. The conclusion is drawn due to the following observations:

The EIRR is greater than the assumed economic discount rate of 10% The ENPV is greater than zero. The benefit-cost ratio is greater than one.

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The detailed working of the economic analysis is provided in the Detailed Project Report.

The likely impact of the project on the environment has been carried and has been provided in the Detailed Project Report.

3.9.2.4 Status Update of Capital Expenditure:

Revised DPR for RMU works was prepared in-house based on information received from the site. Order for review of DPR by AHEC IIT, Roorkee has been placed. Review of DPR is under progress. DPR has been approved by UJVN Limited Board on 13th September 2012. AHEC, IIT Roorkee is being engaged for review, checking and vetting of the technical specification prepared in house by UJVN Limited.

3.9.3 Financing of Capital Expenditure:

3.9.3.1 The Project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of Rs. 240.25 Crores planned during the control period, debt will be Rs. 168.18 Crores and equity contribution will be Rs. 72.08 Crores. Equity will be provided from budgetary support of GoU envisaged for UJVN Limited while debt is yet to be arranged. Year-wise allocation of debt and equity for the control period is provided in the table below:

Table 67: Funding Pattern during the Control Period – Ramganga Project Rs. Crores Year upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total Debt - 27.31 57.01 83.86 150.48 318.65 Equity - 11.70 24.43 35.94 64.49 136.57 Debt 0% 70% 70% 70% 70% 70% Equity 0% 30% 30% 30% 30% 30%

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3.9.4 Capitalization Schedule:

3.9.4.1 The completion schedule for RMU works of various units of Ramganga project is as under:

Unit No Start Date Completion Date

Unit I 15th June 2014 28th February 2015

Unit II 15th June 2015 28th February 2016

Unit III 15th June 2016 28th February 2017

3.9.4.2 Out of capital expenditure of Rs. 455.22 Crores, Rs. 303.48 Crores will get capitalized during the control period. Year-wise capitalization during the control period is provided in the table below:

Table 68: Capex & Capitalization during the Control Period – Ramganga Project Rs. Crores Year upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total Capital Expenditure - 39.01 81.44 119.80 214.97 455.22 Capitalization - - 151.74 151.74 151.74 455.22

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3.10 Maneri Bhali - II Hydroelectric Project (304 MW)

3.10.1 Background:

3.10.1.1 Maneri Bhali Stage-II Hydroelectric Project utilizes a 285 m drop available in river Bhagirathi between the tail waters of Tiloth Power Station (Maneri Bhali Stage-I Project) and the head waters of Tehri Dam. The diversion structure is a baraage situated at Joshiyara, Uttarkashi which is about 152 km from Rishikesh, the nearest railhead. Joshiyara Barrage is designed to divert 142 cumecs of water through a 6 m dia. and 16 km long Head Race Tunnel to feed four Francis Turbines of the Power Station at MB-II.

3.10.1.2 This project has been commissioned in 2008 and is the second Power Project of UJVN Limited on river Bhagirathi.

3.10.1.3 Since its commissioning in the year 2008, Maneri Bhali Stage-II HEP has not been able to operate at its full capacity because of following reasons :

Restriction of reservoir level at 1104 m at Joshiyara Barrage instead of designed maximum level of 1108 m.

Heavy vibrations in the machines due to improper water evacuation through TRC, when load is increased beyond 275-280 MW.

For analyzing the issue of excessive vibrations, UJVN Ltd. approached various agencies and department to carry out the studies regarding TRC and finally the work of carrying out the CFD analysis of TRC was awarded to SVNIT, Surat. The SVNIT faculty members along with Dr. Shrikant Bhave (retired expert of BHEL) visited the site and analyzed the problem. The remedy for the problem of excessive vibrations has been suggested by modifying the geometry of TRC.

3.10.1.4 UJVN Limited has prepared a report on balance capital works to be done in Maneri Bhali – II. The Breakup of Cost for Balance works as per Original DPR as approved by CEA and proposed new works that are to be taken up for operating the Power Station at its full capacity are given in Annexure 10.

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3.10.2 Capital Expenditure:

3.10.2.1 Capital Expenditure for balance works is estimated at Rs. 216.23 Crores for FY 2012-13, FY 2013-14 and FY 2014-15 .Capital expenditure of Rs. 191.23 Crores is projected to be incurred during the control period. The year wise phasing of the capital expenditure during the control period is shown in the table below:

Table 69: Capital Expenditure during the Control Period – Maneri Bhali - II Project Rs. Crores upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total Capital Expenditure 25.00 100.00 91.23 - - 216.23

3.10.2.2 Details of the total cost of balance works is provided in the table on the next page:

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Table 70: Capital Cost – Maneri Bhali - II Project MANERI BHALI - II H. E. PROJECT (304 MW), UTTARAKHAND ABSTRACT OF COST S. No Description Amount (Rs. in Crores) 1 Rehabilitation 15.56 2 Compensation for the affected people 1.14 3 Construction of Protection wall 32.32 4 Modification of tail race channel 24.15 5 Construction of Office Building at Joshiyara 1.03 6 Construciton of Joshiyara colony 1.10 7 Construciton of Road from Joshiyara Bridge to Flushing 2.22 conduit on left Bank (1.2 km) and from Barrage to NH-108 on Right Bank (0.4 km) 8 Balance infrastructure works for affected villages of 9.50 Joshiyara, Gyanshu & Kansain as per their demands 9 Construction of boundary wall, sectrity fencing and gate for 1.21 Shaktipuram colony and Shifting of existing boundary wall of Shaktipuram colony and provide the separate way for villagers behind Shaktipuram colony 10 Construction of 04 Nos Type-IV Residences and 01 Nos Type- 1.10 V Residence in Shaktipuram colony, Chinyalisaur 11 Construction of school building for Saraswati Shishu Mandir 2.00 School in Shaktipuram Colony Chinyalisaur 12 Strengthening of water distribution system of Shaktipuram 0.89 colony, Chinyalisaur 13 Construction of workshop building at Dharasu power house 1.69 of MB-II project 14 Protection work on hill slope behind power house 2.57 15 Testing of surge shaft gate 5.00 16 Centage Charges 60.84 17 Payment to M/sNPCC against claim of Principal Agreement 12.68 in accordance to the decision of High Power Committee 18 Liabilities against major civil contract of MB-II Project a. Reimbursement of Sales Tax 8.15 b. Reimbursement of royalty 0.45 c. Award given by the arbitrator in favour of M/s Hydel 30.73 Construction (P) Ltd against dispute related to swellex rock bolt, Steel fivre as extra items and loss due to flood along with the interest of Rs. 95424/- per day d. Payment against misc. works 0.26 e. Security 0.35 f. Pending Liability of GSI 0.95 g. Expenditure incurred for arbitration 0.35

Total 216.23

3.10.3 Financing of Capital Expenditure:

3.10.3.1 The Project will be financed with the Debt: Equity ratio of 70:30. Out of Capex of Rs. 191.23 Crores planned during the control period, debt will be Rs. 133.86

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Crores and equity contribution will be Rs. 57.37 Crores. Year-wise allocation of debt and equity for the control period is provided in the table below:

Table 71: Funding Pattern during the Control Period – Maneri Bhali - II Project Rs. Crores Year upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total Debt 17.50 70.00 63.86 - - 151.36 Equity 7.50 30.00 27.37 - - 64.87 Debt 70% 70% 70% 0% 0% 70% Equity 30% 30% 30% 0% 0% 30%

3.10.4 Capitalization Schedule:

3.10.4.1 Total capital expenditure of Rs. 191.23 Crores will get capitalized during the control period. Year-wise capitalization during the control period is provided in the table below:

Table 72: Capex & Capitalization during the Control Period – Maneri Bhali - II Project Rs. Crores Year upto 31.03.2013 FY 2013-14 FY 2014-15 FY 2015-16 after 31.03.2016 Total Capital Expenditure 25.00 100.00 91.23 - 216.23 Capitalization 25.00 100.00 91.23 - - 216.23

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3.11 Refurbishment of Asan Barrage, at Dhalipur (Dehradun)

3.11.1 Yamuna Hydel Scheme Stage-IV envisages power generation by utilizing the tail race water of the Yamuna Hydel Scheme Stage-I along with flow of Asan River. To use water from river Asan, Asan Barrage is constructed at Dhalipur in District Dehradun along with a power channel to carry water to Kulhal power house of 30 MW installed capacity which has been constructed at the end of the power channel near village Kulhal. The construction of this project was completed in 1975.

3.11.2 Asan Barrage had been operated & maintained by Irrigation Department- Uttarakhand till 30th April, 2010 and since then it is being run and maintained by UJVN Limited.

3.11.3 In the last 35 years, no major repair of the Asan barrage and its associated structure has been done. Even it faced many floods. Due to record rainfall in August and September 2010, heavy floods have damaged treatment works in upstream as well as in downstream of the barrage.

3.11.4 The Asan Barrage, proposed for refurbishment has spent life of more than 36 years. Since commissioning of the project, it has been continuously under operation for diverting water to generating plants. It underwent heavy floods during monsoon period, every year carrying heavy logs and boulders with it. With the passage of time and continuous operation, a lot of defects in the infrastructure have developed. The sills and other components of Asan Barrage have gone weary. After creation of Uttarakhand state, the government has given a major thrust on the development of Hydo electric projects. A lot of work is being done by Uttarakhand Government towards making Uttarakhand an “Energy state”. Under present scenario, apart from implementation of new projects it has become essential that maximum energy be

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harnessed from existing projects also. To ensure its reliable operation refurbishment of Asan Barrage is essentially required.

3.11.5 The refurbishment shall prevent the leakage of water from Asan Barrage, during lean season, which shall be utilized for generating more electricity. Further, its refurbishment is essential for its life extension and hassle free operation. Repair of damaged structures/components of Asan Barrage will certainly prevent further deterioration of structures/components so that threat to these structures and any loss of power generation may be averted in future.

3.11.6 The cost of Refurbishment of Asan Barrage is Rs 535.32 lacs. The work is to be carried out under World Bank funded DRIP (Dam Rehabilitation and Improvement Project) Scheme. The expenditure shall be done in the year 2013-14 and 2014-15 in the ratio of 40:60, subject to approval by the DRIP Authorities. This fund will be provided as a grant for this project.

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3.12 Refurbishing of Ichari Dam, at Ichari, Koti (Dehradun)

3.12.1 Ichari Dam was built under Yamuna Hydro Electric Scheme Stage-II and it has been in operation since 1975. It is a straight Gravity Dam of 59.25 meter height from deepest foundation level with a live storage capacity of 5.11 million cum for diurnal variation. The total length of the dam at top is about 155 m with seven spilling bays each of 9.50 m clear opening. Spillways are provided with 16.50 m high and 9.5 m wide radial gates. The energy dissipation arrangement consists of slotted roller bucket in all spillway bays. Due to poor site conditions, special treatment on left bank of dam in D/S as well as in upstream has been made.

3.12.2 Ichari Dam was being operated and maintained by Irrigation Department up to 30/4/2010. Since the midnight of 30/4/2010, the dam is being operated and maintained by UJVN Limited.

3.12.3 For the last 35 years the dam has encountered many floods and no major refurbishment of dam and its associated structures/equipment has been carried out. Heavy floods due to record rainfall in August and September 2010 have further damaged the treatment provided in upstream as well as downstream of the dam.

3.12.4 The Ichari dam proposed for refurbishing has spent life of more than 35 years. Since commissioning, the dam is continuously under operation for diverting water to generating plants. Every year it encounters heavy floods during monsoon period, carrying heavy logs and boulders with it. With the passage of time and continuous operation a lot of defects in the Hydro-mechanical equipment have developed along with wear & tear. The sills and other components of Ichari Dam have gone weary. After creation of Uttarakhand state, the government has provided a major thrust on the development of Hydo electric projects. A lot of work is being done by Uttarakhand Government towards making Uttarakhand an “Energy state”. Under

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present scenario, apart from implementation of new projects it has become essential that maximum energy be harnessed from existing projects also.

3.12.5 Since no major repair works have been carried out on Ichari Dam so far, its refurbishment is essentially required. The refurbishing shall prevent the leakage of water from Ichari Dam during lean season which would be utilized for generating more electricity. Further, its refurbishment is essential in view of its life extension and hassle free operation. Repair of damaged structures/components of Ichari Dam will certainly prevent further deterioration of structures/components so that threat to these structures and any loss of power generation may be averted in future.

3.12.6 The cost of Refurbishment of Ichari Dam is Rs 2237.57 lacs. The work is to be carried out under World Bank funded DRIP (Dam Rehabilitation and Improvement Project) Scheme. The expenditure shall be done in the year 2013-14 and 2014-15 in the ratio of 40:60, subject to approval by the DRIP Authorities. This fund will be provided as grant for this project.

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3.13 Rehabilitation Work of Virbhadra Barrage, Pashulok, Rishikesh

3.13.1 Virbhadra barrage was constructed and commissioned in the year 1980 and during its Thirty years of operation, various components of barrage have gone under heavy wear and tear and are posing troubles during operational activity for passing the flood safely into downstream. After construction of Tehri and Koteshwar Dam, Virbhadra Barrage, Pashulok is playing its important role round the year for consistent power generation. In view of its importance and to ensure reliable operation Virbhadra barrage needs to be rehabilitated. Following are the main components where rehabilitation is required:

All gates of barrage, head regulator and silt ejector. Piers and apron of barrage Afflux bund seepage drain of pond. Service road of afflux bund. Painting on steel structures of barrage. Painting on civil structures of barrage. Electro- mechanical components such as motors and brake shoes. Luminaries of barrage. Renovation of Barrage Control Room including improvement of sanitation facility Installation of Trash Rack Cleaning Machine Automation of Barrage

3.13.2 Closure for special repair of submerged parts of Power channel and hydro mechanical components is necessary as the above said project runs throughout the year without any interruption except in high flood condition. A lot of wear & tear of very serious nature in civil structures as well as hydro-mechanical equipment takes place every year and therefore routine maintenance of submerged parts of structures is not possible. Since the commissioning of this project no regular closure have been taken for inspection and repair works of power channel and hydro- mechanical equipments. Lining and bed of power channel is severely damaged and is required to be repaired. In view of expected extensive damage to the components

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leading to loss of generation from projects any delay in the repair of power channel is undesirable.

3.13.3 The cost of Rehabilitation work of Virbhadra Barrage is Rs 625.81 lacs. The work is to be carried out under World Bank funded DRIP (Dam Rehabilitation and Improvement Project) Scheme. The expenditure shall be done in the year 2013-14 and 2014-15 in the ratio of 40:60, subject to approval by the DRIP Authorities. This fund will be provided as grant for this project.

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3.14 Refurbishment of Dakpathar Barrage, at Dakpathar (Dehradun)

3.14.1 A Barrage of 543.3m length with head regulator was commissioned in 1965 as a run- of-river scheme across river Yamuna at Dakpathar in Dehradun. From the barrage a flow of 198 cum/sec is diverted and conveyed through a power channel to Dhakrani (33.75MW) Powerhouse and Dhalipur (51 MW) Powerhouse where heads of 19.80 m and 30.50 m respectively are utilized for power generation. After generating power at Dhalipur power house, the diverted water from Dakpathar Barrage meets Asan river/pond behind Asan Barrage.

3.14.2 Dakpathar Barrage is provided with 6 nos. under sluices and 19 nos. spillway bays to discharge floods of River Yamuna. The head regulator takes off at an angle of 110° towards left bank of barrage. The provision of stop log gates is not available at the barrage. Therefore, a closure of powerhouse is required to carry out the repair work of gates and other submerged components of barrage. No repair work of submerged part has been carried out since 2005. During last seven years several floods have passed through the barrage and especially due to record floods in August and September 2010, the sill beams of gates and other associated structures have got severely damaged. As such restoration works are required to be taken up.

3.14.3 The Dakpathar Barrage proposed for refurbishing has spent life of more than 46 years. Since the commissioning of the project, it is continuously under operation for diverting water to generating plants. Every year it has encountered heavy floods during monsoon period carrying heavy logs and boulders with it. With the passage of time and continuous operation a lot of defects in the installed system have developed. The sills and other components of Dakpathar Barrage have gone weary. After creation of Uttarakhand state, the government has provided a major thrust on the development of Hydroelectric projects. A lot of work is being done by Uttarakhand Government towards making Uttarakhand an “Energy state”. Under

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present scenario, apart from implementation of new projects it has become essential that maximum energy be harnessed from existing projects also.

3.14.4 Since no major repair works have been carried out on Dakpathar Barrage so far, its refurbishment is essentially required. The refurbishing shall prevent the leakage of water from Dakpathar Barrage during lean season which would be utilized for generating more electricity. Further, its refurbishment is essential in view of its life extension and hassle free operation. Repair of damaged structures/components of Dakpathar Barrage will certainly prevent further deterioration of structures/components so that threat to these structures and any loss of power generation may be averted in future.

3.14.5 The cost of Refurbishment of Dakpathar Barrage is Rs 672.21 lacs. The work is to be carried out under World Bank funded DRIP (Dam Rehabilitation and Improvement Project) Scheme. The expenditure shall be done in the year 2013-14 and 2014-15 in the ratio of 40:60, subject to approval by the DRIP Authorities. This fund will be provided as grant to the project.

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3.15 Refurbishment of Maneri Dam at Maneri, Uttrakashi

3.15.1 Maneri Dam is situated across river Bhagirathi at Maneri, 15 Km towards Gangotri from district Uttarkashi. It is a 39 m high concrete gravity dam with 4 nos. ogee spillways having crest elevation at 1280.5 m, each 13 m wide, separated by 4 m wide piers and followed by a roller bucket at an elevation of 1261 m.

3.15.2 The power intake consists of 4 bays with sill beam level at the elevation of 1283.25 m and is located on left bank of river and designed for a maximum discharge of 99 cumecs. Out of this discharge 70 cumec is carried out through 8.86 Km long head race tunnel for power generation at Tiloth Power House (90 MW) & rest is discharged through flushing tunnel. The capacity of the dam reservoir is 0.6 million cubic meters.

3.15.3 Maneri Bhali Stage-I (3 x 30 MW) was commissioned in the year 1984 and it was constructed by UP Irrigation Department and financed by UPSEB. Since then Operation & Maintenance was carried out by Irrigation Department but since 19.10.08, the Operation & Maintenance of Maneri Dam has been taken over from Irrigation department by UJVN Ltd.

3.15.4 During its life, the Maneri Dam has faced several floods including the disastrous flood in August 1978 and due to this flood the reservoir got silted fully up to crest and since then, the total sediment load carried by the river has been passing through the spillway. Further, due to heavy floods in August and September, 2010, the sill beam of gates and other associated structures have got damaged severely.

3.15.5 There is an acute bend just upstream of dam spillway structure with a reverse acute bend about 50 m downstream of spillway structure. In addition to this a protruding rock cliff exists on the left bank downstream of spillway/dam axis. The above topographical features combined with floods induce the asymmetrical flow of water

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in the dam structure in the Upstream as well as Downstream sides. Moreover, the rolling down boulders along with heavy sediment load pass through the spillway, which often damages the surface of spillway and roller bracket.

3.15.6 The refurbishment shall prevent the leakage of water from Maneri Dam, during lean season, which shall be utilized for generating more electricity. Further, its refurbishment is essential in view of its life extension and hassle free operation. Repair of damaged structures/components of Maneri Dam will certainly prevent further deterioration of structures/components so that threat to these structures and any loss of power generation may be averted in future.

3.15.7 The cost for Refurbishment of Maneri Dam is Rs 453.24 lacs. The work is to be carried out under World Bank funded DRIP (Dam Rehabilitation and Improvement Project) Scheme. The expenditure shall be done in the year 2013-14 and 2014-15 in the ratio of 40:60, subject to approval by the DRIP Authorities. This fund will be provided as grant to the project.

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3.16 Special Closure Works of Civil & Hydro Mechanical Structures for Yamuna Hydel Scheme Stage–I (Part-I&II) & Stage-IV

3.16.1 Yamuna Hydroelectric Scheme Stage-I at Dakpathar,46 Kms from Dehradun was launched in 1960 and completed in 1965. Under this scheme the barrage has been constructed across the river Yamuna at Dakpathar for diverting the discharge of Yamuna River through a Power Channel of 198 cumes capacity for power generation through two nos. Power Houses of 33.75 MW and 51 MW capacities located at Dhakrani and Dhalipur respectively.

3.16.2 Under Yamuna Hydel Scheme Stage-IV, Kulhal Power Station constructed during the period 1970-75, the tail race discharge of Dhalipur Power House along with discharge of Asan River was picked up by another barrage constructed across river Asan just downstream of Dhalipur Power House and further the water was carried through a 4 Km long power channel to utilize it for power generation at Kulhal Power House with installed capacity of 30 MW. Since commissioning of the project the channel was operated and maintained by Irrigation Department. From the midnight of 30/4/2010 it has been taken over by UJVN Limited and since then it is being operated and maintained by UJVN Ltd.

3.16.3 Closure for special repair of submerged parts of Dakpathar and Asan Barrages, Power channel and hydro mechanical components is necessary as the above said projects run throughout the year without any interruption except in high flood condition. As such, the routine maintenance of submerged parts of structures cannot be carried out and a lot of wear & tear of very serious nature in civil structures as well as hydro-mechanical equipment takes place every year. To inspect & maintain such parts, regular closures have not been taken since the commissioning of this project. Last closure was allowed for Dakpathar Barrage & Asan Barrage in Jan, 2005 and Feb, 2005. Since then submerged structure/ parts could not be repaired. Lining of power channel is severely damaged and bed of the channel needs to be repaired.

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Any delay in the repair of power channel is not affordable in view of expected extensive damage to the components leading to loss of generation from projects.

3.16.4 The cost of repair work is as under:

Lot-1 (Dakpathar Barrage & Power channel upto silt ejector & escape channel, Rs 410.327 lacs.

Lot-2 Power channel from silt ejector Dakpathar to Skew Bridge Dhalipur including Dhakrani Power House, Rs 633.066 Lacs.

Lot-3 Power channel from Skew bridge Dhalipur to intake of Dhalipur Power House including Dhalipur PH complex, Rs 203.297 lacs.

Lot-4 Closure works of Yamuna Hydel Scheme stage IV (From Asan Barrage to Kulhal Power House, Rs 426.467 Lacs.

3.16.5 As such, the total cost for Special Closure Works of Civil & Hydro Mechanical Structures for Yamuna Hydel Scheme Stage–I (Part-I&II) & Stage-IV is Rs 1673.15 lacs (approx.). Closure works shall be carried out after obtaining approval from Govt. of Uttarakhand.

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3.17 Closure of Chilla HEP for Special Repair of Power Channel, Submerged Parts of Structures & Hydro-Mechanical Components of Virbhadra Barrage, Pashulok, Rishikesh

3.17.1 Chilla HEP is one of the major HEP of UJVN Ltd. with an Installed capacity of 144 MW. The project is RoR scheme on river Ganga. After commissioning of Tehri and Koteshwar Dam, the project utilizes the water released from these upstream projects continuously. Chilla HEP runs throughout the year without any interruption, except in high flood condition for shorter duration. Hence the routine maintenance of submerged parts of structures is not possible. To inspect & maintain such parts, periodic closures have been taken since commissioning of the project. However since the year 2003, no closure has been allowed due to increasing gap between demand & supply of power in the State and hence the submerged parts of structures have undergone intensive damage, especially lining of power channel, right afflux bund, trash rack, piers & floor of barrage, silt excluder tunnels and Under Sluice Gates specially Gate #1. As such it has become imperative to repair the said structures/equipment.

3.17.2 Pashulok barrage proposed for refurbishment have spent a life of approx. 30 years. Since the commissioning of the project, it is continuously under operation for diverting water to generating plants. Every year it has encountered heavy floods during monsoon period which carries heavy logs and rolling boulders. With the passage of time and continuous operation a lot of defects in the installed system have developed. The sills and other components of Pashulok Barrage have gone weary.

3.17.3 Since no major repair works have been carried out on this barrage so far, it is essentially required to carry out the said repair for hassle free operation. The repair shall prevent the leakage of water from the barrage during lean season which would be utilized for generating more electricity. Repair of damaged structure/component

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of the Barrage will certainly prevent further deterioration of structure/component so that threat to these structures and any loss of power generation may be averted in future.

3.17.4 The cost for Special Repair of Power Channel, Submerged Parts of Structures & Hydro-Mechanical equipment of Virbhadra Barrage is Rs 645 lacs. Closure works shall be carried out after obtaining approval from Govt. of Uttarakhand.

Table 73 : Summary of expenses proposed under DRIP Scheme and Closure Works (in Rs. Lakh) Sr. Name of Work Amount FY14 FY15 Sources No. 1 Refurbishment of Asan Barrage, at 535.32 214.13 321.19 Grant Dhalipur (Dehradun) under 2 Refurbishing of Ichari Dam, at Ichari, Koti 2237.57 895.03 1342.54 DRIP (Dehradun) Scheme 3 Rehabilitation Work of Virbhadra 625.81 250.32 375.49 Barrage, Pashulok, Rishikesh. 4 Refurbishment of Dakpathar Barrage, at 672.21 268.88 403.33 Dakpathar (Dehradun) 5 Refurbishment of Maneri Dam at Maneri, 453.24 181.30 271.94 Uttrakashi 6 Special Closure Works of Civil & Hydro 1673.15 1673.15 Debt Mechanical Structures for Yamuna Hydel Equity Scheme Stage–I (Part-I&II) & Stage-IV. ratio of 7 Closure of Chilla HEP for Special Repair of 645.00 645.00 70:30 Power Channel, Submerged Parts Of Structures & Hydro-Mechanical Components of Virbhadra Barrage, Pashulok, Rishikesh. Total 6842.30 4127.81 2714.49

Note: The works proposed to be funded under DRIP (Dam Rehabilitation and Improvement Project) Scheme will be carried out only if approved by DRIP authorities. Similarly the Closure works will be carried out after obtaining approval from Govt. of Uttarakhand. The fund to be

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provided under DRIP will be in the form of grant to UJVNL and so the capital cost of such projects has also not been included in the capital expenditure plan proposed in this Business Plan.

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4 MAJOR SHUTDOWN PLAN OF POWER STATIONS

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4.1 Major Shutdown Plan of Power Stations

4.1.1 Availability of a generating unit is dependent on the outages taken for the unit, both forced and planned. While the forced outages are minimized by having a robust maintenance plan, the planned outages are necessary for the smooth functioning of the unit. Either or all the following is included in an outage:

Schedule Preventive Measures Audit History based Maintenance Overall Operational Constraints Technological Upgradation Performance Improvement Measures Statutory Compliances Life Sustenance, Extension, Enhancement Actions

4.1.2 For enhancing the life of the plant and to get generation on sustained basis from the power station, timely maintenance of the power station and replacement of old equipment is essential. Most of the Power Stations of UJVN Limited are quite old and their units, auxiliaries and associated systems need major repair/renovation, modernization and uprating for enhancing the Generation output, Plant Availability and to cope-up with the technological changes taking place from time to time. Identifying the need and importance of RMU of Old Power Stations, UJVN Limited is proactively taking up RMU of its different Power Stations.

4.1.3 Considering the present power requirement of Uttarakhand state, UJVN Ltd. has staggered the RMU of its Power Stations and the RMU is being done in phases. The outages of various units during routine annual maintenance are staggered and planned based on expected generation from various units and criticality of the outage requirement. The outage plan may change based on the exigencies of the

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business. The proposed outage plan for the various generating units of UJVN Limited during the control period is shown in the table below:

Table 74 : Outage Plan during the Control Period for UJVN Limited

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5 SUMMARY

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5.1 Capital Expenditure & Capitalization

5.1.1 Plant-wise and year-wise capital expenditure of UJVN Limited and its capitalization during the control period is summarised in the table below:

Table 75: Capex & Capitalization during the control period - UJVN Limited

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5.1.2 Plant-wise and year-wise Debt and Equity contribution for capital expenditure of UJVN Limited is summarised below:

Table 76: Debt & Equity for Capital Expenditure during the control period - UJVN Limited

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6 TECHNICAL REPORT OF EXISTING POWER STATIONS

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6.1 Objective of the Technical Report

6.1.1 The objective of this study is to:-

i. Determine Design Energy ii. Determine NAPAF (Normative Annual Plant Availability Factor) iii. To explain special circumstances and abnormal operating conditions which affect plant availability iv. To establish that auxiliary consumption and transformation losses are within limits set by the Commission v. To forecast operating parameters such as Plant Availability, Auxiliary and Transformation losses for the control period

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6.2 TECHNICAL REPORT OF TILOTH POWER STATION

6.2.1 Introduction

6.2.1.1 Tiloth Hydro Power Station with an installed capacity of 90 MW (3x30 MW) is a run of river scheme constructed on river Bhagirathi, a major tributary of river Ganga and situated in District Uttarkashi of Uttarakhand state. The scheme consists of a 39 m high concrete diversion dam. The river inflows are diverted through intake structure with sedimentation basin into a concrete lined head race tunnel of 6.5 km long and 6 m dia. The head race tunnel ends at the 69 m high and 11m dia. surge shaft, where the water is fed through 415 m long 3.8/2.5 m dia. underground penstocks which was trifurcated to feed all the three machines installed in the Power Station.

6.2.1.2 There are three generating units having vertical Francis turbine directly coupled with synchronous generator. The turbine output is 31.6 MW for a rated net head of 145 m. The generators are designed for a nominal output of 34 MVA with lagging power factor of 0.9 and class “B” insulation

6.2.1.3 This Power Station was commissioned in the year 1984. Due to continuous operation of machines for the past 28 years in silt laden water, efficiency of machines has substantially decreased and availability of machines has been adversely affected even in spite of best and timely maintenance and adoption of effective operational strategy.

6.2.2 Determination of Design Energy

6.2.2.1 Tiloth Hydro Power Station is a run-of-river type plant. For computing the Design Energy two methodologies have been considered i.e. (i) on the basis of average of 10 daily discharges as per provision for calculation of NAPAF for Run-of-river type plants as prescribed in UERC MYT 2011 Regulations “To be determined plant-wise, based on 10-day Design Energy data, moderated by past experience where

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available / relevant ”and (ii) the maximum generation possible from the Tiloth Power Station considering that there were no machine and other outages. Due to non-availability of 90% dependable 10 daily inflows pattern as approved in the DPR of the project, Design Energy and NAPAF have been calculated on the basis of available past reliable 10 daily discharge data.

(i) On the basis of Average of 10 daily discharges

Reliable 10 daily (average) discharge data for Tiloth Power Station is available for the period April 2000 to March 2012 and the same has been considered for determination of 90% dependable year and Design Energy (Data is provided in the Annexure 1). Reliable data for periods prior to April 2000 is not available with UJVN Limited. On considering the average daily discharge of the year for the same period, the 90% dependable year is found to be 2008-09, as given in the table below:

Table 77: 90% dependable year – Tiloth Power Station Sl. No. 10 Daily Year % Discharge Dependability Average 1 44.58 2011-12 8.3% 2 43.76 2010-11 16.7% 3 42.67 2007-08 25.0% 4 42.39 2003-04 33.3% 5 42.10 2006-07 41.7% 6 39.69 2004-05 50.0% 7 39.60 2005-06 58.3% 8 39.54 2002-03 66.7% 9 38.97 2009-10 75.0% 10 35.37 2000-01 83.3% 11 35.05 2008-09 91.7% 12 32.62 2001-02 100.0%

For calculation of power following formula has been used:

Power = Head x Flow x Gravity x Turbine Efficiency x Generator Efficiency

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Where power is measured in Watts, head in metres, flow in litres per second, and acceleration due to gravity in metres per second per second. The acceleration due to gravity is approximately 9.81 metres per second per second.

For computation of possible energy generation corresponding to the discharge considered, generator and turbine efficiencies have been considered as 0.97 and 0.92 as per the past design records available with UJVN Limited Design Energy estimation is sensitive to these assumptions. The plant has been in operation for past 28 years and it is quite possible that these parameters may have deteriorated from their designed values. In the absence of detailed technical study on the present efficiency levels of generator and turbine of Tiloth Power Station, UJVN Limited for the present exercise is constrained to use these efficiency levels for computational purpose, though the actual efficiency levels are expected to be much lower than the designed values.

The energy generation corresponding to the 10 (ten) daily discharge for 2008-09 with 95% of the Installed capacity is given in the table below:

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Table 78: Discharge & Generation Data – Tiloth Power Station Sr.no. Month Net Discharge Net Head Power Potential Energy (kWh) (cumecs) (meter) (kW) 1 April-I 27.7 147.5 35,803.3 85,92,800.2 2 April-II 39.1 147.5 50,427.1 1,21,02,500.6 3 April-III 53.0 147.5 68,384.9 1,64,12,381.6 4 May-I 49.9 147.5 64,406.5 1,54,57,557.2 5 May-II 63.9 147.5 82,534.8 1,98,08,346.0 6 May-III 68.6 147.5 88,634.7 2,25,72,000.0 7 June-I 62.2 147.5 80,375.8 1,92,90,181.0 8 June-II 37.5 147.5 48,479.8 1,16,35,160.3 9 June-III 33.2 147.5 42,848.6 1,02,83,654.5 10 July-I 38.5 147.5 49,706.6 1,19,29,572.3 11 July-II 15.2 147.5 19,641.7 47,14,000.2 12 July-III 5.4 147.5 6,929.5 18,29,382.9 13 Aug-I - 147.5 - - 14 Aug-II - 147.5 - - 15 Aug-III - 147.5 - - 16 Sept-I 6.2 147.5 7,996.9 19,19,256.0 17 Sept-III 41.9 147.5 54,062.0 1,29,74,889.7 18 Sept-III 61.4 147.5 79,329.8 1,90,39,156.1 19 Oct-I 69.0 147.5 89,073.8 2,05,20,000.0 20 Oct-II 64.1 147.5 82,793.0 1,98,70,327.5 21 Oct-III 54.5 147.5 70,338.4 1,85,69,336.6 22 Nov-I 48.1 147.5 62,168.7 1,49,20,487.8 23 Nov-II 44.0 147.5 56,821.5 1,36,37,161.6 24 Nov-III 41.0 147.5 52,911.5 1,26,98,762.2 25 Dec-I 37.4 147.5 48,283.6 1,15,88,054.4 26 Dec-II 34.7 147.5 44,829.4 1,07,59,052.3 27 Dec-III 31.9 147.5 41,156.6 1,08,65,350.6 28 Jan-I 29.5 147.5 38,095.4 91,42,885.7 29 Jan-II 27.8 147.5 35,835.6 86,00,547.9 30 Jan-III 26.8 147.5 34,541.8 91,19,022.8 31 Feb-I 26.1 147.5 33,710.2 80,90,440.4 32 Feb-II 24.7 147.5 31,928.2 76,62,768.3 33 Feb-III 24.5 147.5 31,607.3 60,68,605.1 34 March-I 24.8 147.5 32,075.4 76,98,097.8 35 March-II 25.0 147.5 32,236.8 77,36,836.2 36 March-III 25.4 147.5 32,800.9 86,59,430.3 Annual Energy Generation 39,47,68,006.1

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Table 79: Design Energy: Tiloth Power Station Sr. No Particulars Unit Value 1 Generation Lost due to uncontrollable situation % 6.1% 2 Generation loss due to uncontrollable situation kWh 24156595.35 3 Design Energy kWh 370611410.70 4 Design Energy MUs 370.61 5 Availability of FY 08-09 % 72% While determining Design Energy, a 6.1% (based on losses experienced during the period for which the data is available) reduction in the energy generation has been considered. This reduction has been considered to take into account generation loss experienced due to uncontrollable factors such as forced stoppages of machines and outages to prevent damage to the machines due to heavy silting during flash floods, flood passing and grid failure etc. These losses represent Hydrological risk and other uncontrollable risks which UJVN Limited cannot control in spite of its robust operating procedures. This figure of 6.1% has been determined considering generation loss on account of uncontrollable factors as a percentage of maximum possible generation without any unit and other outages for the period 2000- 12 for which data is available with UJVN Limited. The details of these losses are provided in the table below.

Table 80: Uncontrollable Losses – Tiloth Power Station Sr. No % losses B/D of Flushing & System Flood Total (5) Equipment Choking Condition Passing & (1) (2) (3) Any Other Reason (4) Gross losses as % of Max. 1 Grosss Generation 2.1% 5.5% 0.3% 0.3% 8.2% Losses due to uncontrollable 2 factors (5)-(1) 6.1%

(ii) On the basis of Maximum possible plant generation

In view of the limited data size, UJVN Limited has also considered an alternate approach of computing Design Energy on the basis of actual gross generation and generation lost on account of various operational & hydrological reasons

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since 2000-01, for which the data is available. The loss of generation (possible additional generation lost by UJVN Limited) is on account of (i) Equipment break down (ii) Flushing and Choking (iii) System Conditions (iv) Flood passing and other reasons. UJVN Limited computes on a daily basis, the generation opportunity missed by it on account of these reasons. Thus, the maximum energy that Tiloth Power Station possibly could have generated (with 100% Unit availability and with no generation loss on account of any reason) is the gross generation by its Units and the generation loss suffered by it. This is an equally good approach for an existing plant for computing Design Energy when compared with the method of computing Design Energy on the basis of river discharge data as it is based on existing unit efficiencies instead of their design values, considers the impact of other project design related issues and also operational restrictions imposed on the plant. For example it was not anticipated that there shall be huge quantum of generation loss from Tiloth Power Station on account of erosion of underwater parts of turbines during the monsoon period, as a result of which the plant will have to remain under shutdown during heavy monsoon period. However, the Power Station is run on partial load during monsoon period as per the power requirements of the state, provided the silt content is within permissible limit.

The maximum possible year wise generation has been computed in the table below:

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Table 81: Year wise Maximum Possible Generation (MU) – Tiloth Power Station Sr. no. Actual Gross Generation Maximum Year % Generation Loss (MU) Possible Dependabi (MU) Generation lity (MU) 1 457.46 153.05 610.51 2002-03 8.33 2 372.64 196.54 569.18 2001-02 16.67 3 516.11 28.58 544.69 2011-12 25.00 4 488.52 52.19 540.71 2003-04 33.33 5 504.41 5.60 510.00 2010-11 41.67 6 466.14 6.83 472.97 2007-08 50.00 7 467.49 3.32 470.82 2006-07 58.33 8 456.54 13.47 470.02 2004-05 66.67 9 456.30 3.54 459.84 2005-06 75.00 10 449.08 2.95 452.03 2009-10 83.33 11 403.80 15.93 419.74 2008-09 91.67 12 408.52 3.66 412.18 2000-01 100.00

On re-arranging the data in the descending order and considering the 90% dependable year, the Design Energy for the Tiloth Power Station is computed to be 394.05 MUs as given in the table below:

Table 82: Design Energy – Tiloth Power Station Sr. No. Particular Unit Value 1 Dependable Year FY 2008-09 2 Maximum Possible Generation MUs 419.74 3 Plant Availability for FY 2008-09 % 72% 4 Energy losses due to uncontrollable factors % 6.1% 5 Energy losses due to uncontrollable factors MUs 25.68 6 Design Energy (2)-(5) MUs 394.05

6.2.3 Determination of NAPAF

6.2.3.1 The Actual average plant availability during the last 12 years is given in the table below:

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Table 83: Plant Availability during FY 2000 - 12 – Tiloth Power Station Sr. No (1) Month (2) Total Reserve Forced Planned Maintenance Total Plant Running Outage Outage Annual Capital hours(max) Availability Hrs. of all (Hrs.) (4) (Hrs.) (5) Mainten Major (Hrs.) (8) % (9) the units ance repairs (Hrs.) (Col. 3+Col. (Hrs.) (3) (Hrs.) (6) (7) 4)/Col.8 1 April 16795 5775 967 2376 7 25920 87% 2 May 25084 983 705 12 0 26784 97% 3 June 23757 1013 962 134 54 25920 96% 4 July 10435 5421 1589 9339 0 26784 59% 5 August 1728 828 221 24007 0 26784 10% 6 Sept 18697 663 291 6268 0 25919 75% 7 Oct 24506 1864 152 262 0 26784 98% 8 Nov 16877 6231 44 2768 0 25920 89% 9 Dec 13096 5496 690 7502 0 26784 69% 10 Jan 10887 7892 789 6471 744 26783 70% 11 Feb 9536 6442 5 8425 0 24408 65% 12 March 11876 5591 22 9295 0 26784 65% Total 183274 48199 6437 76859 805 315574 73%

6.2.3.2 The Tiloth Power Station experiences excessive forced shut downs during the monsoon period. The reasons for these forced shut downs have been provided in the section below. The average plant availability during the last 12 years is around 73%. The plant availability is showing sign of improvement and during the last five years it has improved over the last 12 years’ average.

6.2.4 Special Circumstances and Abnormal Operating Conditions

6.2.4.1 Since its commissioning, Tiloth Power Station operates on base load during monsoon period and as a peaking station during non-monsoon period when discharge in the river reduces and Power Station has to be run on partial load. But due to silting of Maneri Dam, the peaking capacity has also reduced and the Power Station meets evening and morning peaks at partial load during the lean discharge period.

6.2.4.2 Study of the available inflow data revealed that the maximum capacity can be generated between May to September (excluding the heavy monsoon period

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during which machines had to be closed due to high ppm for about 45 days). The Power Station is run on partial capacity between October to April. Lean discharge period is again utilised for planned annual or capital maintenance.

6.2.4.3 The silt which passes through the turbines is highly abrasive and contains substantial amount of quartzite angular particles which in turn causes severe damages to the underwater parts of the units, as a result of this machines are losing efficiency at a rapid pace. Though efforts are on to combat this problem since it was detected after few months of operation of Power Station, but no viable solution could be found except hard coating of underwater parts, changing material for runner manufacturing and also changing design of runner which slightly improved availability of machines

6.2.4.4 To avoid extensive damage to the underwater parts, every year the underwater parts of machines are taken out when silt ppm goes beyond 2000 at Maneri Dam which corresponds to 1200 ppm at bell mouth of penstocks during last week of July to first week of September. This period is utilised in carrying out necessary maintenance of the machines. However, the Power Station is sometimes run on partial load during the monsoon period provided that the silt ppm level is within the permissible limits. Sometimes machines have to be stopped to allow passing of excessive discharge of water and trash during flood.

6.2.4.5 Thus it can be concluded that quite a good amount of energy is lost during monsoon season which is beyond the control of UJVN Limited. Annual loss of energy during Monsoon due to flushing and choking over the period 2000-12 has been calculated in Table 80 & 84, which is around 5.5% of the gross generation and 67% of the total generation loss. Such annual loss should therefore be appropriately accounted for while computing Design Energy and Plant Availability.

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6.2.5 Plant Outages and Breakdowns

6.2.5.1 Apart from above facts, when flood recedes lot of silt having substantial quartzite particles are lodged in cavities and caves on both banks of river which gets dislodged when level of river starts rising as a result of snow melting during summer season and is carried to the machines through water conductor system causing severe damage to under water parts and frequent plant outages which is beyond the control of UJVN Limited

6.2.5.2 The forced outage data for the period 2000-12 has revealed that 25% of the total energy loss is on this account. The table below provides the details.

Table 84: % Generation Loss on account of various Factors – Tiloth Power Station Sr. No. Month↓ B/D of Flushing & System Flood Total Equipment Choking Condition passing & (in MU) (in MU) (in MU) & Grid fail Any Other (in MU) Reasons (in MU) 1 April 20.58 0.00 0.55 0.18 21.31 2 May 10.26 4.26 6.43 0.02 20.96 3 June 9.83 10.36 8.99 0.14 29.31 4 July 33.11 155.83 0.68 2.16 191.78 5 August 1.29 134.63 0.00 5.17 141.09 6 September 40.83 15.86 0.96 0.23 57.88 7 October 4.70 1.70 0.65 0.79 7.84 8 November 0.00 2.53 0.00 0.00 2.53 9 December 1.90 0.00 0.13 0.00 2.04 10 January 0.00 0.22 0.05 0.00 0.28 11 Feburary 0.00 0.00 0.04 0.00 0.04 12 March 0.12 0.00 0.04 10.45 10.62 Total 122.62 325.38 18.51 19.15 485.65 % Generation loss 25% 67% 4% 4% 100%

6.2.6 Auxiliary Consumption and Transformation Losses

6.2.6.1 The analysis of auxiliary consumption data of past 12 years reveals that the auxiliary consumption of Tiloth Power Station is around 0.30% of the Gross Generation. Similarly the transformation losses of past 9 years for which the data is

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available reveals that these losses are 0.7% of the gross generation. Both auxiliary consumption and transformation losses together constitute around 1% of the Gross Generation.

Table 85: Auxiliary and Transformation Losses – Tiloth Power Station Sr. No. Particulars Unit Value 1 Total Gross Generation (2000-12) MUs 5447.0 2 Total Aux. consumption (2000-12) MUs 16.5 3 Aux. consumption as a % of Gross Generation % 0.3% 4 Total Gross Generation (2003-12) MUs 4208.4 5 Total Transformation loss (2003-12) MUs 29.1 6 Transformation loss as a % of Gross Generation % 0.7% 7 Total Aux. and Transformation losses (2003-12) MUs 42.3 Total Aux. and Transformation losses as a % of 8 % 1.0% Gross Generation

6.2.6.2 UJVN Ltd. has taken steps to reduce the auxiliary consumption and transformation losses. Data of previous 4 years as shown in the table below and which has already been submitted to Hon’ble UERC, shows improvement in auxiliary and transformation losses.

Sr. No Year Transformation Auxiliary & line losses Consumption 1 FY 2010-11 0.3% 0.2% 2 FY 2009-10 0.3% 0.2% 3 FY 2008-09 0.7% 0.3% 4 FY 2007-08 0.2% 0.3% 5 Average 0.4% 0.3% 6.2.7 Inferences

6.2.7.1 Design Energy

Discharge data on 10 daily (average) basis for Tiloth Power Station is available for the period April 2000 to March 2012. The data for each 10 daily discharge of the year is selected on the basis of 90% dependability. Correspondingly the Design Energy is calculated (refer the earlier Table 79) to be 370.61 MU after accounting for uncontrollable energy loss of 6.1%. Design Energy was also calculated based

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on maximum possible generation (refer Table-82) basis which comes to 394.05 MU.

Tiloth Power Station is quite old Power Station and has been under operation in heavy silt laden water since its commissioning in the year 1984. This long operation period has resulted into excessive wear and tear of the hydro- mechanical and electro-mechanical equipment, thereby causing breakdown of machines. The condition of these equipment is deteriorating with passage of time. UJVN Ltd. is taking proactive action by taking up comprehensive RMU of the Project for revival and life extension of the project.

Keeping in view the long operational life of the project, it is proposed that Design Energy for Tiloth Power Station may be considered as 394.05 MU which is the Design Energy computed using the second approach mentioned earlier. However, after completion of the proposed RMU works of the Project, UJVN Ltd. shall approach the Commission to revise the Design Energy of the Project.

6.2.7.2 NAPAF

UERC has prescribed principle for determination of Normative Plant Availability for run of the river plants. Based on the principle given by UERC the annual plant availability has been calculated in the above table 79, which comes to 72%

Based on actual running hours, reserve hours, forced outage hours and plant outage hours for last 12 years, average annual plant availability has been calculated to be 73% and this may be taken as NAPAF for Tiloth Power Station for the base year of the control period.

6.2.7.3 Auxiliary Consumption and Transformation Losses

As explained in the earlier section these losses are within the limit of 1% prescribed by the UERC in its regulations for Surface hydroelectric power generating stations with static excitation system.

6.2.8 Projections for the control period

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6.2.8.1 RMU works are proposed for the Tiloth Power Station. The proposed RMU works are likely to result in (i) Extension of the Plant life by around 25 years (ii) Higher Plant Availability (iii) Increased operating efficiencies of plant. The RMU works for the plant is likely to be completed during the control period. The unit wise schedule for implementing RMU is as given below:

Name of Date of Start Date of Unit Commissioning Unit-1 01.11.13 31.03.15 Unit-2 01.06.15 31.03.16 Unit-3 01.06.16 31.03.17

6.2.9 Impact of RMU works on Energy Generation

6.2.9.1 The proposed RMU of Tiloth Power Station is likely to result in refurbishment of turbines and generators leading to increased efficiencies.

6.2.9.2 Improvement in sedimentation handling, hard coating of underwater parts of turbines, reduction in closure period to around 30 days in August could yield energy gains of the order of 8.5% if the same level of water discharge is considered pre and post RMU. Primary purpose of RMU is life extension of the project apart from increase in generation. After RMU, generation will increase from 446 MU to 484 MU (as per DPR) subject to same water discharge.

6.2.10 Availability

6.2.10.1 The annual maintenance schedule and the RMU schedule proposed for Tiloth Power Station under RMU works for the Control period is as given below:

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FY2013-14

Unit No. Start Date End date Days Reasons 1 01-11-2013 31-03-2015 516 RMU Interim repair of spherical 15-07-2013 31-07-2013 17 2 valve of Unit 2 15-01-2014 31-01-2014 17 Interim repair of Unit-2 01-02-2014 15-02-2014 15 Interim repair of of Unit 3 Major repair of Unit-3 3 (15/7/13 to 30/8/14), Major 15-07-2013 30-08-2013 47 repair of Spherical Valve of Unit-3 (15/7/13 to 15/8/13) FY2014-15

Unit No. Start Date End date Days Reasons 1 01-11-2013 31-03-2015 516 RMU Major repair of Unit 2 15-07-2014 30-08-2014 47 2 (15/7/14 to 30/8/14) 15-01-2015 31-01-2015 17 Interim repair of Unit-2 Interim repair of Unit 3, 15-07-2014 31-07-2014 17 Interim repair of 3 spherical valve of Unit 3 15-11-2014 14-12-2014 30 Repair of Unit-3 FY2015-16

Unit No. Start Date End date Days Reasons Interim repair of of Unit 1 01-12-2015 30-12-2015 30 1, Interim repair of spherical valve of Unit 1 2 01-06-2015 31-03-2016 305 RMU 01-01-2016 30-01-2016 30 Interim repair of Unit 3 Interim repair of Unit 3, 3 15-07-2015 31-07-2015 17 Interim repair of spherical valve of Unit 3

6.2.10.2 After implementation of RMU works full capacity of the plant is likely to be available for the entire year except for the closure during monsoon period and annual maintenance period. The plant availability during the control year considering maintenance schedule given above and forced outages expected (based on past data) during monsoon months is expected to be as given below:

Particulars Base Year 2013-14 2014-15 2015-16 Plant Availability (%) 73% 76% 54% 64% The plant availability expected post RMU is likely to be around 80 %.

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6.2.11 Auxiliary Consumption and Transformation losses

6.2.11.1 As stated above the auxiliary and transformation losses are within the limits prescribed by the Commission. During the control period these are expected to be within the limits prescribed by the Commission.

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6.3 TECHNICAL REPORT OF CHIBRO POWER STATION

6.3.1 Introduction

6.3.1.1 Chibro Hydro Power Station with an installed capacity of 240 MW (4x60 MW) is a run of river scheme constructed on river Tons, a major tributary of river Yamuna and is situated in District Dehradun of Uttarakhand state. The scheme consists of a 39 m high concrete diversion dam at Ichari. The river inflows are diverted through intake structure with sedimentation basin into a concrete lined head race tunnel of 6.22 km long and 7 m dia. The head race tunnel ends at the 92 m high and 20m dia. surge shaft, where the water is fed through 123 m long 3.8 m dia. 4 nos. underground steel lined penstocks to feed all the four machines installed in Chibro underground Power Station.

6.3.1.2 There are four generating units having vertical Francis turbine directly coupled with synchronous generator. The turbine output is 63 MW for a rated net head of 110 m. The generators are designed for a nominal output of 63 MVA with lagging power factor of 0.9 and class “B” insulation

6.3.1.3 This Power Station was commissioned in the year 1975. Due to operations of machines for past 36 years in silt laden water, efficiency of machines has substantially decreased and availability of machines has been adversely affected even in spite of best and timely maintenance.

6.3.1.4 Though this Power Station has an installed capacity of 4x60 MW but due to discharge limitations in HRT maximum generating capacity is restricted to around 185 MW. As such while analyzing data for calculating Design Energy, installed capacity of the Power Station has been considered as 185 MW.

6.3.2 Determination of Design Energy

6.3.2.1 Chibro Power Station is a run-of-river type plant. For computing the Design Energy two methodologies have been considered i.e. (i) on the basis of average of 10 daily

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discharges as per provision for calculation of NAPAF for Run-of-river type plant prescribed in UERC MYT 2011 Regulations “To be determined plant-wise, based on 10-day Design Energy data, moderated by past experience where available /relevant “and (ii) the maximum generation possible from the Chibro Power Station considering that there were no machine and other outages. Due to non-availability of 90% dependable 10 daily inflows pattern as approved in the DPR of the project, Design Energy and NAPAF have been calculated on the basis of available past years reliable 10 daily discharge data.

(i) On the basis of Average of 10 daily discharges

Reliable 10 daily (average) discharge data for Chibro Power Station is available for the period April 1993 to March 2012 and the same has been considered for determination of 90% dependable year and corresponding Design Energy (Data is provided in the annexure 2). Considering the average daily discharge data of the years for which data was available, the 90% dependable year is found to be 2004-05, as given in the table below:

Table 86: 90% Dependable year – Chibro Power Station

Sr. No. 10 Daily Year % Average Dependability Discharge 1 129.08 98-99 5.26 2 112.19 95-96 10.53 3 107.07 97-98 15.79 4 106.70 96-97 21.05 5 103.75 94-95 26.32 6 102.52 02-03 31.58 7 100.13 93-94 36.84 8 97.22 03-04 42.11 9 97.05 11-12 47.37 10 96.95 08-09 52.63 11 92.38 99-00 57.89 12 92.27 05-06 63.16 13 90.88 10-11 68.42 14 88.26 00-01 73.68 15 87.34 01-02 78.95 16 86.76 06-07 84.21 17 85.16 07-08 89.47 18 72.25 04-05 94.74 19 66.10 09-10 100.00

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For computation of possible energy generation corresponding to the discharge considered, generator and turbine efficiencies have been considered as 0.973 and 0.92 as per the past design records available with UJVN Limited. Design Energy estimation is sensitive to these assumptions. The plant has been in operation for 36 years and it is quite possible that these parameters may have deteriorated from their design values. In the absence of detailed technical study on the present efficiency levels of generator and turbine of Chibro, UJVN Limited for the present is constrained to use these efficiency levels for computational purpose though the actual efficiency levels are expected to be lower.

The energy generation corresponding to the 10 (ten) daily discharge for 2004-05 with 95% of the Installed capacity is given in the table below:

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Table 87: Discharge & Generation Data – Chibro Power Station Sl.no. Month Net Discharge Net Head Power Potential Energy (kWh) (cumecs) (meter) (kW) 1 April-I 45.1 110.0 43565.1 10455628.5 2 April-II 48.9 110.0 47235.8 11336590.5 3 April-III 53.0 110.0 51196.3 12287102.2 4 May-I 60.0 110.0 57958.0 13909927.0 5 May-II 77.1 110.0 74476.1 17874256.3 6 May-III 74.4 110.0 71832.8 18963867.2 7 June-I 58.0 110.0 56026.1 13446262.8 8 June-II 84.2 110.0 81334.4 19520264.3 9 June-III 67.0 110.0 64719.8 15532751.9 10 July-I 90.8 110.0 87709.8 21050356.3 11 July-II 78.0 110.0 75345.4 18082905.2 12 July-III 94.3 110.0 91064.4 24040990.6 13 Aug-I 148.6 110.0 143542.7 34450252.7 14 Aug-II 167.1 110.0 161413.1 38739146.8 15 Aug-III 155.5 110.0 150164.0 39643292.1 16 Sept-I 125.7 110.0 121422.1 29141297.2 17 Sept-III 103.7 110.0 100170.8 24040990.6 18 Sept-III 76.7 110.0 74089.7 17781523.4 19 Oct-I 63.3 110.0 61145.7 14674973.0 20 Oct-II 83.3 110.0 80465.1 19311615.4 21 Oct-III 54.1 110.0 52250.0 13794011.0 22 Nov-I 43.1 110.0 41633.2 9991964.3 23 Nov-II 36.5 110.0 35257.8 8461872.3 24 Nov-III 35.6 110.0 34388.4 8253223.4 25 Dec-I 39.0 110.0 37672.7 9041452.6 26 Dec-II 36.4 110.0 35161.2 8438689.1 27 Dec-III 34.7 110.0 33545.4 8855986.9 28 Jan-I 35.7 110.0 34485.0 8276406.6 29 Jan-II 33.7 110.0 32553.1 7812742.4 30 Jan-III 37.1 110.0 35828.6 9458750.4 31 Feb-I 45.9 110.0 44337.9 10641094.2 32 Feb-II 66.7 110.0 64430.0 15463202.2 33 Feb-III 60.9 110.0 58803.3 11290224.1 34 March-I 77.9 110.0 75248.8 18059721.9 35 March-II 102.5 110.0 99011.6 23762792.0 36 March-III 99.9 110.0 96508.9 25478349.7 Annual Energy Generation 611364477

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Table 88: Design Energy- Chibro Power Station

Sr. no Particulars Units Value 1 Generation Loss due to uncontrollable situation % 4.15% 2 Energy loss during monsoon and forced outages kWh 2,53,67,508.8 3 Design Energy kWh 58,59,96,968.1 4 Design Energy (MU) MU 586.0 5 Plant Availability of FY 04-05 % 77.9 While determining Design Energy, a 4.15% (based on losses experienced during the period for which data is available) reduction in the energy generation has been considered. This reduction has been considered to take into account generation loss experienced due to uncontrollable factors such as forced stoppages of machines and outages to prevent damage to the machines due to heavy silting during flash floods, flood passing and grid failure etc. These losses represent Hydrological risk and other uncontrollable risks which UJVN Limited cannot control in spite of its robust operating procedures. The figure of 4.15% has been determined considering generation loss on account of uncontrollable factors as a percentage of maximum possible generation without any unit and other outages on the basis of past data of the period 1998-99 to 2011-12. The details of these losses are provided in the table below.

Table 89: Uncontrollable Losses – Chibro Power Station Sr. No % losses B/D of Flushing & System Flood Total (5) Equipment Choking Condition Passing & (1) (2) (3) Any Other Reason (4) Gross lossesas a % of Max 1 Gross Generation 1.54% 2.44% 0.30% 1.41% 5.69% Losses due to Uncontrollable 2 factor (5)-(1) 4.15%

(ii) On the basis of Maximum possible plant generation

In view of the limited data size, UJVN Limited has also considered an alternate approach of computing Design Energy on the basis of actual gross generation

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and generation lost on account of various operational & hydrological reasons since 1998-99, for which the data is available. The loss of generation (possible additional generation lost by UJVN Limited) is on account of (i) Equipment break down (ii) Flushing and Choking (iii) System Condition (iv) Flood passing and other reasons. UJVN Limited computes on a daily basis, the generation opportunity missed by it on account of these reasons. Thus the maximum that Chibro Power Station possibly could have generated (with 100% Unit availability and with no generation loss on account of any reason) is the gross generation by its Units and the generation loss suffered by it. This is an equally good approach for an existing plant for computing Design Energy when compared with the method of computing Design Energy on the basis of river discharge data as it is based on existing unit efficiencies instead of their design values, considers the impact of other project design related issues and also operational restrictions imposed on the plant. The maximum possible year wise generation has been computed in the table below:

Table 90: Year wise Maximum Possible Generation (MU) – Chibro Power Station Sr. no. Actual Gross Generation Maximum Year % Generation Loss (MU) Power Dependabi (MU) Generation lity (MU) 1 1,063.50 95.24 1,158.74 1998-99 7.14 2 870.54 33.70 904.24 2002-03 14.29 3 848.96 54.38 903.34 2011-12 21.43 4 837.69 47.57 885.26 2008-09 28.57 5 795.65 83.69 879.35 2010-11 35.71 6 804.96 64.24 869.20 2005-06 42.86 7 824.23 37.18 861.41 2003-04 50.00 8 766.46 88.18 854.64 2000-01 57.14 9 803.08 11.96 815.04 1999-00 64.29 10 743.39 54.36 797.75 2001-02 71.43 11 755.69 27.92 783.61 2007-08 78.57 12 756.05 24.23 780.27 2006-07 85.71 13 636.41 18.97 655.38 2004-05 92.86 14 587.97 27.42 615.39 2009-10 100.00

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On re-arranging the data in the descending order and considering the 90% dependable year, the Design Energy for the Chibro Power Station is computed to be 628.18 MUs.

Table 91: Design Energy – Chibro Power Station Sr. No. Particular Unit Value 1 Dependable Year FY 2004-05 2 Maximum Possible Generation MUs 655.38 3 Plant Availability for FY 04-05 % 77.92 4 Energy losses due to uncontrollable factors % 4.15% 5 Energy losses due to uncontrollable factors MUs 27.19 6 Design Energy (2)-(5) MUs 628.18

6.3.3 Determination of NAPAF

6.3.3.1 Actual plant availability during the last 12 years is given in table 91 below:

Table 92: Plant Availability during FY 2000 - 12 – Chibro Power Station Sr. No (1) Month (2) Total Reserve Forced Planned Maintenance Total hours Plant Running Outage Outage Annual Capital (max) Availability Hrs. of all (Hrs.) (4) (Hrs.) (5) Mainten Major (Hrs.) (8) % (9) the units ance repairs (Hrs.) (Col. 3+Col. (Hrs.) (3) (Hrs.) (6) (7) 4)/Col.8 1 April 13569 9460 475 10336 720 34560 67% 2 May 18596 9259 237 7353 267 35712 78% 3 June 20203 8808 1081 4312 156 34560 84% 4 July 25925 6513 1266 1957 51 35712 91% 5 August 27615 4465 1537 2086 9 35712 90% 6 Sept 25706 7509 199 1146 0 34560 96% 7 Oct 17182 13396 580 4158 396 35712 86% 8 Nov 10594 13597 703 8956 710 34560 70% 9 Dec 8558 13465 779 12166 744 35712 62% 10 Jan 7897 12872 1401 13127 415 35712 58% 11 Feb 7777 11105 75 12891 696 32544 58% 12 March 11739 11605 65 11681 622 35712 65% Total 195361 122054 8398 90169 4786 420768 75%

6.3.3.2 The Chibro plant experiences excessive forced shut downs during the monsoon seasons. The reasons for these forced shut downs have been provided in the section below. The average plant availability during the last 12 years is around 75%.

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6.3.4 Special Circumstances and Abnormal Operating Conditions

6.3.4.1 Since its commissioning, this Power Station operates on base load during monsoon and as a peaking station during non-monsoon period when discharge in the river reduces and Power Station has to be run on part load. This Power Station meets evening and morning peaks during lean discharge period as per instructions by SLDC. But due to silting of Ichari Dam the peaking capacity has also reduced. Lean discharge period is again utilised for planned annual or capital maintenance.

6.3.4.2 Annual loss of energy during Monsoon due to flushing and choking over the period 1998-12 has been calculated in Table no. 89 & 93, which is around 2.4% of the gross generation and 43% of the total generation loss. Such annual loss should therefore be appropriately accounted for while computing Design Energy and plant availability.

6.3.5 Plant Outages and Breakdowns

6.3.6 Apart from above facts, when flood recedes lot of silt having substantial silt particles are lodged in cavities and caves on both banks of river which gets dislodged when level of river starts rising as a result of snow melting during summer season and is carried to the machines through water conductor system causing severe damage to under water parts and frequent plant outages which becomes beyond control of UJVN Limited.

6.3.6.1 The forced outage data for the period 1998-2012 has revealed that 27% of the total energy loss is on this account. The table below provides the details.

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Table 93: % Generation Loss on account of various Factors – Chibro Power Station Sr. No. Month↓ B/D of Flushing & System Flood Total Equipment Choking Condition passing & & Grid fail Any Other Reasons 1 April 0.75 4.32 0.65 0.27 5.99 2 May 4.03 3.96 2.59 0.00 10.57 3 June 16.01 33.71 5.33 6.93 61.98 4 July 67.24 106.19 12.32 30.07 215.82 5 August 85.99 77.16 11.80 64.57 239.52 6 September 6.55 46.95 1.46 53.06 108.01 7 October 0.35 11.44 1.18 8.49 21.47 8 November 0.00 1.08 0.00 0.98 2.06 9 December 0.00 0.00 0.00 0.00 0.00 10 January 0.00 0.00 0.03 0.58 0.61 11 Feburary 0.00 0.97 0.37 0.00 1.34 12 March 0.00 1.27 0.00 0.39 1.66 Total 180.92 287.04 35.72 165.34 669.03 Generation Lost 27% 43% 5% 25% 100%

6.3.7 Auxiliary Consumption and Transformation Losses

6.3.7.1 The analysis of auxiliary consumption data of past 14 years (1998–12) reveals that the auxiliary consumption of Chibro Power Station is around 0.2% of the Gross Generation. Similarly the transformation losses of past 9 years (2003-12) for which the data is available has been analysed. The transformation losses are 1.4% of the gross generation. Both auxiliary and transformation losses together constitute around 1.6 % of the Gross Generation.

Table 94: Auxiliary and Transformation Losses – Chibro Power Station Sr. No. Particulars Unit Value 1 Total Gross Generation (1998-12) MUs 11094.58 2 Total Aux. consumption (1998-12) MUs 25.39 3 Aux. consumption as a % of Gross Generation % 0.23% 4 Total Gross Generation (2003-12) MUs 6847.60 5 Total Transformation loss (2003-12) MUs 92.95 6 Transformation loss as a % of Gross Generation % 1.36% 7 Total Aux. and Transformation losses (2003-12) MUs 104.68 Total Aux. and Transformation losses as % of 8 % 1.53% Gross Generation

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6.3.7.2 UJVN Ltd. has taken steps to reduce the auxiliary consumption and transformation losses. Data of previous 4 years, which has already been submitted to Hon’ble UERC, as shown below, shows improvement in auxiliary and transformation losses. Hence the same may be considered for the control period.

Sr. No Year Transformation Auxiliary & line losses Consumption 1 FY 2010-11 1.3% 0.1% 2 FY 2009-10 1.2% 0.1% 3 FY 2008-09 1.4% 0.2% 4 FY 2007-08 1.6% 0.2% 5 Average 1.4% 0.2%

6.3.8 Inferences

6.3.8.1 Design Energy

The discharge data for Chibro Power Station is available on 10 daily (average) basis for the period April 1993 to March 2012. The discharge data for each 10 daily of the year is selected for the 90% dependable year. Correspondingly the Design Energy is calculated (refer earlier table no.88) to be 586 MU after accounting for uncontrollable energy loss of 4.15%.

Design Energy was also calculated on the basis of maximum possible generation (refer earlier Table no. 91) which comes to 628.18 MU.

Chibro Power Station is quite old Power Station and has been under operation since its commissioning in the year 1975. This long operation period has resulted into excessive wear and tear of the hydro mechanical and electro mechanical equipment, thereby causing breakdown of machines. The condition of these equipment is deteriorating with passage of time. UJVN Ltd. is taking proactive action by taking up comprehensive RMU of the Project for revival and life extension of the project.

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Keeping in view the long operational life of the project, it is proposed that Design Energy for Chibro Power Station may be considered as 628.18 MU which is the Design Energy computed using the second approach mentioned earlier. However, after completion of the proposed RMU works of the Project, UJVN Ltd. shall approach the Commission to revise the Design Energy of the Project.

6.3.8.2 NAPAF

UERC has prescribed principle for determination of Normative Plant Availability for run of the river plant. Based on the principle given by UERC the annual plant availability has been calculated in the table no.91 which comes to 77.92%.

Based on actual running hours, reserve hours, forced outage hours and plant outage hours for last 10 years, average annual plant availability has been calculated, which comes to 75% and this may be taken as NAPAF for Chibro Power Station for the base year of the control period.

6.3.8.3 Auxiliary Consumption and Transformation Losses

The auxiliary and transformation losses exceed the norms set by UERC for underground hydroelectric power generating stations with static excitation system by 0.3%. As indicated earlier these losses are showing sign of reduction. UJVN Limited proposes to take remedial measures during the proposed RMU to reduce these losses within the prescribed limits prescribed by the Commission.

6.3.9 Projections for the control period

6.3.9.1 RMU works are proposed for the Chibro Power Station. The proposed RMU works are likely to result in (i) Extension of the Plant life by around 25 years (ii) Higher Plant Availability (iii) Increased operating efficiencies of plant. The RMU works for the plant is likely to be completed during the control period. The unit wise schedule for implementing RMU is as given below:

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Name of Date of Start Date of Unit Commissioning Unit-1 01.11.15 31.03.17 Unit-2 01.06.17 31.03.18 Unit-3 01.06.18 31.03.19 Unit 4 01.06.19 31.03.20

6.3.10 Impact of RMU works on Energy Generation

6.3.10.1 Primary purpose of RMU is life extension of the project apart from increase in generation. After RMU, generation will increase from 865 MU to 942 MU (as per DPR) subject to same water discharge.

6.3.11 Availability

6.3.11.1 The annual maintenance schedule and the RMU schedule proposed for Chibro Power Station under RMU works for the Control period is as given below:

FY 2013-14

Unit No. Start Date End date Days Reasons 1 01-11-2013 10-12-2013 40 Annual Maintenance 2 14-12-2013 22-01-2014 40 Annual Maintenance 3 27-01-2014 07-03-2014 40 Annual Maintenance 4 13-01-2014 21-02-2014 40 Annual Maintenance FY 2014-15

Unit No. Start Date End date Days Reasons 1 01-11-2014 10-12-2014 40 Annual Maintenance 2 14-12-2014 22-01-2015 40 Annual Maintenance 3 27-01-2015 07-03-2015 40 Annual Maintenance 4 13-01-2015 21-02-2015 40 Annual Maintenance FY 2015-16

Unit No. Start Date End date Days Reasons 1 01-11-2015 31-03-2017 517 RMU 2 14-12-2015 22-01-2016 40 Annual Maintenance 3 27-01-2016 06-03-2016 40 Annual Maintenance 4 13-01-2016 21-02-2016 40 Annual Maintenance

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6.3.11.2 After implementation of RMU works full capacity of the plant is likely to be available for the year except during monsoon period and annual maintenance period. The plant availability during the control year considering maintenance schedule given above and forced outages expected (based on past data) during monsoon months is expected to be as given below:

Particulars Base Year 2013-14 2014-15 2015-16 Plant Availability (%) 75% 85% 87.5% 79.9%

6.3.11.3 The plant availability expected post RMU is likely to be around 85%.

6.3.12 Auxiliary Consumption and Transformation losses

6.3.12.1 The normative auxiliary and transformation losses can be achieved after implementation of RMU works wherein energy efficient motors, starters, heating, air conditioning, illumination, power transformation and switching system would be adopted. The Chibro Power Station is expected to achieve normative loss level in the year after the control period. During the control period losses are likely remain at the existing levels.

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6.4 TECHNICAL REPORT OF DHAKRANI POWER STATION

6.4.1 Introduction

6.4.1.1 The Dhakrani (3X11.25 MW) Power Station is located on the downstream of the Dakpathar Barrage at a distance of 8 km on the power channel which takes off from the Barrage constructed on river Yamuna. River Tons is a major tributary of Yamuna and meets just before the location of Barrage. Tail water of Khodri Power Station also falls in Yamuna just upstream of Barrage. The Tail water of this Power Station feeds the Dhalipur Power Station on the downstream on the same power channel.

6.4.1.2 There are three generating units having vertical Kaplan turbine directly coupled with synchronous generator. The turbine output is 14300 HP for a rated net head of 19.8 m. The generators are designed for a nominal output of 11.25 MW with lagging power factor of 0.9 and class “B” insulation.

6.4.1.3 This Power Station was commissioned in the year 1965. Due to continuous operations of machines for the past 46 years, efficiency of machines has substantially decreased and availability of machines has been adversely affected even in spite of best and timely maintenance and adoption of effective operational strategy.

6.4.2 Determination of Design Energy

6.4.2.1 Dhakrani is a Run of the river Power Station. For computing the Design Energy two methodologies have been considered i.e. (i) on the basis of average of 10 daily discharges as per provision for calculation of NAPAF for Run-of-river type plant as prescribed in UERC MYT 2011 Regulations “To be determined plant-wise, based on 10-day Design Energy data, moderated by past experience where available /relevant” and (ii) the maximum generation possible from the Dhakrani Power Station considering that there were no machine and other outages. Due to non- availability of 90% dependable 10 daily inflows pattern as approved in the DPR of

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the project, Design Energy and NAPAF have been calculated on the basis of available past reliable 10 daily discharge data.

(i) On the basis of Average of 10 daily discharges

Reliable 10 daily (average) discharge data for Dhakrani Power Station is available for the period April 1994 to March 2012 and the same has been considered for determination of 90% dependable year and Design Energy (This data has been provided in the annexure 3). Reliable data for periods prior to April 1994 is not available with UJVN Limited. The year wise average daily discharge data was considered for the same period and the 90% dependable year is found to be 2004-05 as given in table 94 below:

Table 95: 90% Dependable Year– Dhakrani Power Station Sr. No. 10 Daily Year % Average Dependability Discharge 1 141.40 98-99 5.56 2 124.86 97-98 11.11 3 122.09 02-03 16.67 4 118.77 96-97 22.22 5 114.33 95-96 27.78 6 111.72 03-04 33.33 7 111.25 05-06 38.89 8 111.03 11-12 44.44 9 108.92 94-95 50.00 10 106.59 08-09 55.56 11 104.96 00-01 61.11 12 104.66 10-11 66.67 13 102.08 99-00 72.22 14 101.51 06-07 77.78 15 100.70 07-08 83.33 16 96.15 01-02 88.89 17 87.39 04-05 94.44 18 75.28 09-10 100.00 For computation of possible energy generation corresponding to the discharge considered, generator and turbine efficiencies have been considered as 0.97 and 0.9114 as per the past design records available with UJVN Limited. Design energy estimation is sensitive to these assumptions.

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The plant has been in operation for past 46 years and it is quite possible that these parameters may have deteriorated from their designed values. In the absence of detailed technical study on the present efficiency levels of generator and turbine of Dhakrani Power Station, UJVN Limited for the present exercise is constrained to use these efficiency levels for computational purpose though the actual efficiency levels are expected to be much lower than the designed values.

The energy generation corresponding to the 10 (ten) daily discharge for 2004-05 with 95% of the Installed capacity is given in the table below:

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Table 96: Discharge & Generation Data – Dhakrani Power Station Sr.no. Month Net Discharge Net Head Power Potential Energy (kWh) (cumecs) (meter) (kW) 1 April-I 56.8 19.8 9,754.2 23,41,020.0 2 April-II 59.0 19.8 10,124.1 24,29,791.1 3 April-III 63.9 19.8 10,971.0 26,33,049.9 4 May-I 71.4 19.8 12,266.5 29,43,955.0 5 May-II 84.4 19.8 14,498.0 34,79,508.0 6 May-III 82.8 19.8 14,217.9 37,53,528.2 7 June-I 69.3 19.8 11,906.6 28,57,574.1 8 June-II 103.4 19.8 17,762.0 42,62,870.2 9 June-III 82.5 19.8 14,173.2 34,01,575.7 10 July-I 130.8 19.8 22,462.0 53,90,890.4 11 July-II 119.2 19.8 20,466.9 49,12,045.4 12 July-III 117.6 19.8 20,195.2 53,31,544.8 13 Aug-I 182.9 19.8 31,412.1 75,38,913.5 14 Aug-II 188.0 19.8 32,282.6 76,95,000.0 15 Aug-III 190.9 19.8 32,782.9 84,64,500.0 16 Sept-I 177.6 19.8 30,500.7 73,20,158.9 17 Sept-III 175.4 19.8 30,112.6 72,27,019.2 18 Sept-III 133.7 19.8 22,958.5 55,10,035.0 19 Oct-I 113.6 19.8 19,511.2 46,82,699.3 20 Oct-II 136.4 19.8 23,426.6 56,22,379.6 21 Oct-III 98.4 19.8 16,901.1 44,61,884.1 22 Nov-I 77.2 19.8 13,260.9 31,82,615.1 23 Nov-II 65.3 19.8 11,215.1 26,91,612.5 24 Nov-III 58.2 19.8 9,987.6 23,97,027.4 25 Dec-I 57.0 19.8 9,788.2 23,49,180.0 26 Dec-II 52.6 19.8 9,028.7 21,66,898.3 27 Dec-III 48.1 19.8 8,262.9 21,81,405.0 28 Jan-I 48.8 19.8 8,375.4 20,10,104.0 29 Jan-II 14.2 19.8 2,435.6 5,84,554.4 30 Jan-III - 19.8 - - 31 Feb-I - 19.8 - - 32 Feb-II - 19.8 - - 33 Feb-III - 19.8 - - 34 March-I 36.3 19.8 6,237.0 14,96,869.7 35 March-II 128.3 19.8 22,029.8 52,87,159.2 36 March-III 122.0 19.8 20,945.2 55,29,528.4 Annual Energy Generation 13,21,36,896.3

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Table 97- Design Energy: Dhakrani Power Station Sr. No Particulars Unit Value 1 Generation Loss due to uncontrollable situation % 7.3% 2 Energy loss during monsoon and forced outages kWh 9633453.9 3 Design Energy kWh 122503442.4 4 Design Energy (MU) MUs 122.5 5 Plant Availability of FY 04-05 % 83.5 While determining Design Energy, a 7.3% (based on losses experienced during the period for which data is available) reduction in the energy generation has been considered. This reduction has been considered to take into account generation loss experienced due to uncontrollable factors such as forced stoppages of machines and outages to prevent damage to the machines due to heavy silting (and accumulation of trash) during flash floods, flood passing and grid failure etc. These losses represent hydrological risk and other uncontrollable risks which UJVN Limited cannot control in spite of its robust operating procedures. The figure of 7.3% has been determined considering generation loss on account of uncontrollable factors as a percentage of maximum possible generation without any unit and other outages on the basis of past data of the period 1997-98 to 2011-12. The details of these losses are provided in the table below:

Table 98: Uncontrollable Losses – Dhakrani Power Station Sr. No % losses B/D of Flushing System Flood Total (5) Equipment & Condition Passing & (1) Choking (3) Any Other (2) Reason (4) Gross losses as % of Max 1 Gross Generation 2.6% 3.6% 0.2% 3.5% 9.9% Losses due to uncontrollable 2 factors (5)-(1) 7.3%

(ii) On the basis of Maximum Possible Plant generation

In view of the limited data size, UJVN Limited has also considered an alternate approach of computing Design Energy on the basis of actual gross generation

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and generation lost on account of various operational & hydrological reasons since 1997-98, for which the data is available. The loss of generation (possible additional generation loss to UJVN Limited) is on account of (i) Equipment break down (ii) Flushing and choking (iii) System Conditions (iv) Flood passing and other reasons. UJVN Limited computes on a daily basis, the generation opportunity missed by it on account of these reasons. Thus the maximum energy that Dhakrani Power Station possibly could have generated (with 100% Unit availability and with no generation loss on account of any reason) is the gross generation by its Units and the generation loss suffered by it. This is an equally good approach for an existing plant for computing Design Energy when compared with the method of computing Design Energy on the basis of river discharge data as it is based on existing unit efficiencies instead of their design values, considers the impact of other project design related issues and also the operational restrictions imposed on the plant. The maximum possible year wise generation has been computed in table 99 below:

Table 99: Year wise Maximum Possible Generation (MU) – Dhakrani Power Station Sr. no. Actual Gross Generation Maximum Year % Generation Loss (MU) Possible Dependabi (MU) Generation lity (MU) 1 159.39 55.15 214.54 1998-99 6.67 2 163.83 22.73 186.56 1997-98 13.33 3 173.78 4.79 178.57 2002-03 20.00 4 164.63 10.89 175.52 2005-06 26.67 5 160.31 11.64 171.95 2003-04 33.33 6 152.75 9.76 162.50 2011-12 40.00 7 143.02 18.52 161.53 2010-11 46.67 8 146.52 10.26 156.78 2008-09 53.33 9 143.19 12.92 156.11 2000-01 60.00 10 148.92 4.95 153.87 2007-08 66.67 11 147.35 4.88 152.22 2006-07 73.33 12 107.77 41.48 149.24 1999-00 80.00 13 115.38 22.54 137.92 2001-02 86.67 14 125.90 2.87 128.77 2004-05 93.33 15 105.08 4.72 109.80 2009-10 100.00

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On re-arranging the above data in the descending order and considering the 90% dependability, the Design Energy for the Dhakrani Power Station is computed to be 119.38 MUs as given in table below;

Table 100: Design Energy – Dhakrani Power Station Sr. No. Particular Unit Value 1 Dependable Year FY 2004-05 2 Maximum Possible Generation MUs 128.77 3 Plant Availability for FY 2004-05 % 83.55 4 Energy losses due to uncontrollable factors % 7.3% 5 Energy losses due to uncontrollable factors MUs 9.39 6 Design Energy (2)-(5) MUs 119.38

6.4.3 Determination of NAPAF

6.4.3.1 Actual average plant availability during the last 12 years is given in table below:

Table 101: Plant Availability during FY 2000 - 12 – Dhakrani Power Station Sr. No (1) Month (2) Total Reserve Forced Planned Maintenance Total hours Plant Running Outage Outage Annual Capital (max) Availability Hrs. of all (Hrs.) (4) (Hrs.) (5) Mainten Major (Hrs.) (8) % (9) the units ance repairs (Hrs.) (Col. 3+Col. (Hrs.) (3) (Hrs.) (6) (7) 4)/Col.8 1 April 13168 7727 64 4961 0 25920 81% 2 May 16875 7223 194 2492 0 26784 90% 3 June 18275 6630 55 960 0 25920 96% 4 July 22734 3230 76 744 0 26784 97% 5 August 23481 2489 64 750 0 26784 97% 6 Sept 22895 2788 237 0 0 25920 99% 7 Oct 18275 8375 134 0 0 26784 99% 8 Nov 11308 8703 253 5656 0 25920 77% 9 Dec 9564 8704 21 8495 0 26784 68% 10 Jan 8997 9049 626 8112 0 26784 67% 11 Feb 7561 8197 17 8633 0 24408 65% 12 March 10520 6512 167 9585 0 26784 64% Total 183653 79627 1908 50388 0 315576 83%

6.4.3.2 The plant availability for this period is around 83%. The Dhakrani Power Station experiences excessive forced shut downs during the monsoon period. The reasons for these forced shut downs have been provided in the section below.

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6.4.4 Special Circumstances and Abnormal Operating Conditions

6.4.4.1 Since its commissioning, Dhakrani Power Station operates on base load during monsoon period and as a peaking station during non-monsoon period when discharge in the river reduces and Power Station has to be run on partial load. But due to silting of reservoir of Dakpathar Barrage the peaking capacity has also reduced and the Power Station meets evening and morning peaks during lean discharge period as per requirement of SLDC.

6.4.4.2 Study of the available inflow data revealed that the maximum capacity that can be generated in between May to September and partially between October to April. Lean discharge period is again utilised for planned annual or capital maintenance.

6.4.4.3 Average annual loss of energy during Monsoon due to flushing and choking over the period 1997-12 has been calculated in Table 98 & 102, which is around 3.6% of the gross generation and 36% of the total generation loss. Such annual loss should therefore be appropriately accounted for while computing Design Energy and plant availability.

6.4.5 Plant Outages and Breakdowns

6.4.5.1 The forced outage data for the period 1997-2012 has revealed that 27% of the total energy loss is on this account. The table below provides the details.

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Table 102: % Generation Loss on account of various Factors – Dhakrani Power Station Sr. No. Month↓ B/D of Flushing & System Flood Total Equipment Choking Condition passing & (in MU) (in MU) (in MU) & Grid fail Any Other (in MU) Reasons (in MU) 1 April 0.74 0.00 0.20 4.13 5.07 2 May 1.98 0.27 0.39 2.77 5.41 3 June 5.14 5.01 0.50 0.67 11.31 4 July 5.45 31.25 1.21 5.67 43.58 5 August 15.82 35.39 0.78 20.57 72.56 6 September 16.01 8.53 0.34 29.69 54.56 7 October 10.47 2.81 0.35 3.08 16.71 8 November 4.54 0.02 0.11 0.12 4.79 9 December 1.91 0.00 0.06 0.67 2.64 10 January 0.20 0.07 0.12 0.10 0.48 11 Feburary 0.56 1.86 0.12 2.85 5.39 12 March 0.59 0.26 0.19 14.56 15.60 Total 63.42 85.45 4.36 84.86 238.09 % Generation Loss 27% 36% 2% 36% 100%

6.4.6 Auxiliary Consumption and Transformation Losses

6.4.6.1 The analysis of auxiliary consumption data of past 15 years reveals that the auxiliary consumption of Dhakrani Power Station is around 1.19% of the Gross Generation. Dhakrani Power Station acts as source of electrical energy for providing the auxiliary supply to Chibro, Khodri, Kulhal, Dhalipur Power Stations, Ichari Dam, Asan Barrage, Dakpathar Barrage and to residential colonies of Dakpathar, Koti, Dhalipur and Kulhal.

6.4.6.2 For providing these power supplies, various 33 kV lines emanates from Dhakrani Power Station. This 33 kV network is large and diversified. There are many 33/11 kV and 11kV/0.415 kV transformers along with 11 kV and LT lines. Consequently there are transformation and distribution losses. These losses are getting accounted as Auxiliary and Transformation losses. However the analysis of data post 2008 reveals that these losses have come down and are likely to reduce further.

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Table 103: Auxiliary and Transformation Losses – Dhakrani Power Station Sr. No Particulars Unit Value 1 Total Gross Generation 1997-12) MUs 2157.79 2 Total Aux. consumption (1997-12) MUs 25.71 3 Aux. consumption as a % of Gross Generation % 1.19%

6.4.6.3 UJVN Ltd. has taken steps to reduce the auxiliary consumption and transformation losses. Data of previous 4 years, which has already been submitted to Hon’ble UERC, as shown below, shows improvement in auxiliary and transformation losses.

Sr. No Year Transformation Auxiliary & line losses Consumption 1 FY 2010-11 2.4% 1.1% 2 FY 2009-10 4.6% 1.5% 3 FY 2008-09 0.3% 1.2% 4 FY 2007-08 1.9% 1.4% 5 Average 2.3% 1.3%

6.4.7 Inferences

6.4.7.1 Design Energy

The discharge data for Dhakrani Power Station is available on 10 daily (average) basis for the period April 1994 to March 2012. The data for each 10 daily discharge of the year is selected on the basis of 90% dependability. Correspondingly the Design Energy is calculated (refer the earlier table 97) to be 122.5 MU after accounting for uncontrollable energy loss of 7.3%.

Design Energy was also calculated based on maximum possible generation (refer Table-100) which comes to 119.38 MU after considering uncontrollable loss of 7.3%.

Dhakrani Power Station is quite old Power Station and has been under operation since its commissioning in the year 1965. This long operation period has resulted into excessive wear and tear of the hydro mechanical and electro mechanical equipment, thereby causing breakdown of machines. The condition of these

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equipments is deteriorating with passage of time. UJVN Ltd. is taking proactive action by taking up comprehensive RMU of the Project for revival and life extension of the project.

Keeping in view the long operational life of the project, it is proposed that Design Energy for Dhakrani Power Station may be considered as 119.38 MU which is the Design Energy computed using the second approach mentioned earlier. However, after completion of the proposed RMU works of the Project, UJVN Ltd. shall approach the Commission to revise the Design Energy of the Project.

6.4.7.2 NAPAF

Based on actual running hours, reserve hours, forced outage hours and plant outage hours for last 12 years plant average annual plant availability has been calculated in earlier table no. 101 which comes to 83% which may be taken as NAPAF for Dhakrani Power Station for base year of the control period.

6.4.7.3 Auxiliary Consumption and Transformation Losses

The auxiliary and transformation losses exceed the norms set by UERC for surface hydroelectric power generating stations with rotary excitation system by 7.7%. The steps are being taken to control losses and improve the loss accounting procedure. UJVN Limited proposes to take remedial measures during the proposed RMU to reduce these losses within the prescribed limits prescribed by the Commission.

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6.4.8 Projections for the control period

6.4.8.1 RMU works are proposed for the Dhakrani Power Station. The proposed RMU works are likely to result in (i) Extension of the Plant life by around 25 years (ii) Higher Plant Availability (iii) Increased operating efficiencies of plant.

6.4.8.2 The RMU works for the plant is likely to be completed during the control period. The unit wise schedule for implementing RMU is as given below:

Name of Date of Start Date of Unit Commissioning Unit-1 01.10.14 30.06.15 Unit-2 01.10.15 30.06.16 Unit-3 01.10.16 30.06.17

6.4.9 Impact of RMU works on Energy Generation

6.4.9.1 The proposed RMU of Dhakrani Power Station is likely to result in refurbishment of turbines and generators leading to increased efficiencies. This could yield energy generation gains of the order of 14 % if the same level of water discharge is considered pre and post RMU. Primary purpose of RMU is life extension of the project apart from increase in generation. After RMU, generation will increase from 161 MU to 184 MU (as per DPR) subject to same water discharge.

6.4.10 Availability

6.4.10.1 The annual maintenance schedule and the RMU schedule proposed for Dhakrani Power Station under RMU works for the Control period is as given below:

FY2013-14

Unit No. Start Date End date Days Reasons 1 01-11-2013 15-12-2013 45 Annual Maintenance 2 16-12-2013 29-01-2014 45 Annual Maintenance 3 30-01-2014 15-03-2014 45 Annual Maintenance FY2014-15

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Unit No. Start Date End date Days Reasons 1 01-10-2014 30-06-2015 273 RMU 2 01-11-2014 15-12-2014 45 Annual Maintenance 3 16-12-2014 29-01-2015 45 Annual Maintenance FY2015-16

Unit No. Start Date End date Days Reasons 1 16-12-2015 14-01-2016 30 Annual Maintenance 2 01-10-2015 30-06-2016 274 RMU 3 01-11-2015 15-12-2015 45 Annual Maintenance

6.4.10.2 After implementation of RMU works, full capacity of the plant is likely to be available for the entire year except during monsoon period and annual maintenance period. The plant availability during the control year considering maintenance schedule given above and forced outages expected (based on past data) during monsoon months is expected to be as given below:

Particulars Base Year FY 2013-14 FY 2014-15 FY 2015-16 Plant Availability (%) 83% 87% 74.67% 67.76%

6.4.10.3 The plant availability expected post RMU is likely to be around 88%.

6.4.11 Auxiliary Consumption and Transformation losses

6.4.11.1 The normative auxiliary and transformation losses can be achieved after implementation of RMU works wherein energy efficient motors, starters, heating, air conditioning, illumination, power transformation and switching system would be adopted. The Dhakrani Power Station is expected to achieve normative auxiliary consumption and transformation loss level after completion of RMU works.

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6.5 TECHNICAL REPORT OF DHALIPUR POWER STATION

6.5.1 Introduction

6.5.1.1 The Dhalipur Power Station of 51 MW (3X17 MW) is located on the downstream of the Dhakrani Power Station at a distance of 5km on the power channel which takes off from the Dakpathar Barrage. The Power Station was commissioned during December 1965 to March, 1970. The 5 Km long power channel ends at 42.5 m wide and 8.8 m deep Fore bay. From fore bay three steel lined 53 m long and 5 m dia. penstocks are laid to feed water to each of the 3 units installed in the Power Station. The surface Power Station comprising 3 units of 17 MW each is located on the power channel and the water from the tail race flows into Asan River. The Power Station's design head is 30.48 m. The Dhalipur Power Station is a low head scheme located on power channel with a design discharge of 199.2 cum.

There are three generating units having vertical Francis turbine directly coupled with synchronous generator. The turbine output is 24,000 HP for a rated net head of 30.48 m. The generators are designed for a nominal output of 19 MVA with lagging power factor of 0.9 and class “B” insulation

6.5.1.2 This Power Station was commissioned in the year Dec 1965 to March 1970. Due to continuous operations of machines for past 46 years, efficiency of machines has substantially decreased and availability of machines has been adversely affected even in spite of best and timely maintenance and adoption of effective operational strategy.

6.5.2 Determination of Design Energy

6.5.2.1 Dhalipur Power Station is a run of the river Power Station. For computing the Design Energy two methodologies have been considered i.e. (i) on the basis of average of 10 daily discharges for calculation of NAPAF for Run-of-river type plant as per provision of UERC MYT 2011 Regulations “To be determined plant-wise, based on 10-day Design Energy data, moderated by past experience where

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available /relevant” and (ii) the maximum generation possible from the Dhalipur Power Station considering that there were no machine and other outages. Due to non-availability of 90% dependable 10 daily inflows pattern as approved in the DPR of the project, Design Energy and NAPAF have been calculated on the basis of available past reliable 10 daily discharge data.

(i) On the basis of Average of 10 daily discharges

Reliable 10 daily (average) discharge data for Dhalipur Power Station is available for the period April 1994 to March 2012 and the same has been considered for determination of 90% dependable year and Design Energy (this data is provided in the annexure 4). Reliable data for periods prior to April 1994 is not available with UJVN Limited. The yearly average daily discharge data was considered for the same period and the 90% dependable year is found to be 2004-05, as given in the table below:

Table 104: 90% Dependable year – Dhalipur Power Station Sr. No. 10 Daily Year % Average Dependability Discharge 1 141.40 98-99 5.56 2 124.86 97-98 11.11 3 122.09 02-03 16.67 4 118.77 96-97 22.22 5 114.33 95-96 27.78 6 111.72 03-04 33.33 7 111.25 05-06 38.89 8 111.03 11-12 44.44 9 108.92 94-95 50.00 10 106.59 08-09 55.56 11 104.96 00-01 61.11 12 104.66 10-11 66.67 13 102.08 99-00 72.22 14 101.51 06-07 77.78 15 100.70 07-08 83.33 16 96.15 01-02 88.89 17 87.39 04-05 94.44 18 75.28 09-10 100.00

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For computation of possible energy generation corresponding to the discharge considered, generator and turbine efficiencies have been considered as 0.97 and 0.90 as per the past design records available with UJVN Limited. Design Energy estimation is sensitive to these assumptions. The plant has been in operation for past 46 years and it is quite possible that these parameters may have deteriorated from their designed values. In the absence of detailed technical study on the present efficiency levels of generator and turbine of Dhalipur Power Station UJVN Limited for the present exercise is constrained to use these efficiency levels for computational purpose though the actual efficiency levels are expected to be much lower than the designed values.

The energy generation corresponding to the 10 (ten) daily discharge for 2004-05 with 95% of the Installed capacity is given in the table below:

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Table 105: Discharge & Generation Data – Dhalipur Power Station Sr.no. Month Net Discharge Net Head Power Potential Energy (kWh) (cumecs) (meter) (kW) 1 April-I 56.8 30.5 14,827.8 35,58,675.4 2 April-II 59.0 30.5 15,390.1 36,93,619.9 3 April-III 63.9 30.5 16,677.5 40,02,601.4 4 May-I 71.4 30.5 18,646.8 44,75,220.4 5 May-II 84.4 30.5 22,038.9 52,89,335.3 6 May-III 82.8 30.5 21,613.2 57,05,884.0 7 June-I 69.3 30.5 18,099.6 43,43,909.5 8 June-II 103.4 30.5 27,000.6 64,80,154.7 9 June-III 82.5 30.5 21,545.3 51,70,867.3 10 July-I 130.8 30.5 34,145.4 81,94,901.9 11 July-II 119.2 30.5 31,112.5 74,66,991.1 12 July-III 117.6 30.5 30,699.6 81,04,688.4 13 Aug-I 182.9 30.5 47,750.8 1,14,60,195.2 14 Aug-II 188.0 30.5 49,074.0 1,16,28,000.0 15 Aug-III 190.9 30.5 49,834.6 1,27,90,800.0 16 Sept-I 177.6 30.5 46,365.2 1,11,27,657.9 17 Sept-III 175.4 30.5 45,775.3 1,09,86,072.7 18 Sept-III 133.7 30.5 34,900.1 83,76,018.2 19 Oct-I 113.6 30.5 29,659.8 71,18,353.1 20 Oct-II 136.4 30.5 35,611.7 85,46,797.6 21 Oct-III 98.4 30.5 25,692.0 67,82,683.4 22 Nov-I 77.2 30.5 20,158.4 48,38,016.8 23 Nov-II 65.3 30.5 17,048.4 40,91,624.7 24 Nov-III 58.2 30.5 15,182.6 36,43,814.5 25 Dec-I 57.0 30.5 14,879.5 35,71,079.8 26 Dec-II 52.6 30.5 13,724.9 32,93,986.2 27 Dec-III 48.1 30.5 12,560.8 33,16,038.4 28 Jan-I 48.8 30.5 12,731.8 30,55,637.2 29 Jan-II 14.2 30.5 3,702.5 8,88,603.8 30 Jan-III - 30.5 - - 31 Feb-I - 30.5 - - 32 Feb-II - 30.5 - - 33 Feb-III - 30.5 - - 34 March-I 36.3 30.5 9,481.0 22,75,449.8 35 March-II 128.3 30.5 33,488.4 80,37,216.1 36 March-III 122.0 30.5 31,839.6 84,05,650.9 Annual Energy Generation 20,07,20,545.5

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Table 106: Design Energy- Dhalipur Power Station Sr. No Parameter Unit Value 1 Generation Loss due to uncontrollable situation % 5.01% 2 Energy loss during monsoon and forced outages kWh 10064099.5 3 Design Energy kWh 190656446.1 4 Design Energy (MU) MUs 190.7 5 Plant Availability of FY 04-05 % 76.5 While determining Design Energy, a 5.01% (based on losses experienced during the operation of the plant) reduction in the energy generation has been considered. This reduction has been considered to take into account generation loss due to uncontrollable factors such as forced stoppages of machines and outages to prevent damage to the machines due to heavy silting during flash floods, flood passing and grid failure etc. These losses represent Hydrological risk and other uncontrollable risks which UJVN Limited cannot control in spite of its robust operating procedures. The figure of 5.01% has been determined considering generation loss on account of uncontrollable factors as a percentage of maximum possible generation without any unit and other outages on the basis of past data of the period 1998-99 to 2011-12. The details of these losses are provided in the table below:

Table 107: Uncontrollable Losses – Dhalipur Power Station Sr. No % losses B/D of Flushing & System Flood Total (5) Equipment Choking Condition Passing & (1) (2) (3) Any Other Reason (4) Gross losses as % of Max 1 Gross Generation 1.44% 4.13% 0.13% 0.76% 6.46% Losses due to uncontrollable 2 factors (5)-(1) 5.01%

(ii) On the basis of Maximum possible plant generation

In view of the limited data size, UJVN Limited has also considered an alternate approach of computing Design Energy on the basis of actual gross generation

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and generation lost on account of various operational & hydrological reasons considering data available since 1998-99. The loss of generation (possible additional generation loss to UJVN Limited) is on account of (i) Equipment break down (ii) Flushing and Choking (iii) System Condition (iv) Flood passing and other reasons. UJVN Limited computes on a daily basis, the generation opportunity missed by it on account of these reasons. Thus the maximum energy that Dhalipur Power Station possibly could have generated (with 100% Unit availability and with no generation loss on account of any reason) is the gross generation by its Units and the generation loss suffered by it. This is an equally good approach for an existing plant for computing Design Energy when compared with the method of computing Design Energy on the basis of river discharge data as it is based on existing unit efficiencies instead of their design values, considers the impact of other project design related issues and also operational restrictions imposed on the plant. The maximum possible year wise generation has been computed in the table below:

Table 108: Year wise Maximum Possible Generation (MU) – Dhalipur Power Station Sr. no. Actual Gross Generation Maximum Year % Generation Loss (MU) Possible Dependabi (MU) Generation lity (MU) 1 305.03 16.84 321.87 1998-99 7.14 2 259.01 6.28 265.30 2002-03 14.29 3 236.14 24.35 260.48 2005-06 21.43 4 230.22 24.96 255.18 2003-04 28.57 5 229.58 15.96 245.54 2011-12 35.71 6 224.44 14.25 238.69 2008-09 42.86 7 210.82 25.38 236.20 2010-11 50.00 8 218.21 14.27 232.48 2000-01 57.14 9 210.70 21.22 231.92 2007-08 64.29 10 212.04 16.70 228.74 1999-00 71.43 11 214.41 8.92 223.33 2006-07 78.57 12 193.45 11.71 205.16 2001-02 85.71 13 185.35 6.50 191.85 2004-05 92.86 14 160.15 5.99 166.14 2009-10 100.00

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On re-arranging the data in the descending order and considering the 90% dependable year, the Design Energy for the Dhalipur Power Station is computed to be 182.23 MUs as given in the table below:

Table 109: Design Energy – Dhalipur Power Station Sr. No. Particular Unit Value 1 Dependable Year FY 2004-05 2 Maximum Possible Generation MUs 191.85 3 Plant Availability for FY 2004-05 % 76.51 4 Energy losses due to uncontrollable factors % 5.01% 5 Energy losses due to uncontrollable factors MUs 9.62 6 Design Energy (2)-(5) MUs 182.23

6.5.3 Determination of NAPAF

6.5.3.1 Actual average plant availability during the last 11 years is given in table below:

Table 110: Plant Availability during FY 2001- 12 – Dhalipur Power Station Sr. No (1) Month (2) Total Reserve Forced Planned Maintenance Total hours Plant Running Outage Outage Annual Capital (max) Availability Hrs. of all (Hrs.) (4) (Hrs.) (5) Mainten Major (Hrs.) (8) % (9) the units ance repairs (Hrs.) (Col. 3+Col. (Hrs.) (3) (Hrs.) (6) (7) 4)/Col.8 1 April 11732 5848 974 3766 1440 23760 74% 2 May 15652 6258 475 1662 505 24552 89% 3 June 16997 6050 457 256 0 23760 97% 4 July 21716 2779 57 0 0 24552 100% 5 August 20935 2111 1499 7 0 24552 94% 6 Sept 20561 2342 857 0 0 23760 96% 7 Oct 16888 7346 318 0 0 24552 99% 8 Nov 10383 8372 0 5005 0 23760 79% 9 Dec 8758 6758 222 8814 0 24552 63% 10 Jan 8389 8552 13 6854 744 24552 69% 11 Feb 6994 6472 139 8115 672 22392 60% 12 March 9490 5957 615 7746 744 24552 63% Total 168495 68845 5626 42225 4105 289296 82%

6.5.3.2 The Dhalipur Power Station experiences forced shut downs during the monsoon period. The reasons for these forced shut downs have been provided in the section below. The average plant availability during the last 11 year is around 82%.

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6.5.4 Special Circumstances and Abnormal Operating Conditions

6.5.4.1 Since its commissioning, Dhalipur Power Station operates on base load during monsoon period and as a peaking station during non-monsoon period when discharge in the river reduces and Power Station has to be run on partial load. But due to silting of Dakpathar Barrage the peaking capacity has also reduced and Power Station meets evening and morning peaks during lean discharge period as per requirement of SLDC.

6.5.4.2 Study of the available inflow data revealed that the maximum capacity can be generated between May to September and partially between October to April. Lean discharge period is again utilised for planned annual or capital maintenance.

6.5.4.3 Annual loss of energy during Monsoon due to flushing and choking over the period 1998-12 has been calculated in table 107 & 111, which is around 64% of the total generation loss. Such annual loss should therefore be appropriately accounted for while computing Design Energy and plant availability.

6.5.5 Plant Outages and Breakdowns

6.5.5.1 The forced outage data for the period 1998-2012 has revealed that 22% of the total energy loss is on this account. The table below provides the details.

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Table 111: % Generation Loss on account of various Factors – Dhalipur Power Station Sr. No. Month↓ B/D of Flushing & System Flood Total Equipment Choking Condition passing & (in MU) (in MU) (in MU) & Grid fail Any Other (in MU) Reasons (in MU) 1 April 0.62 0.00 0.24 4.38 5.23 2 May 0.79 0.38 0.72 0.13 2.02 3 June 1.08 7.59 0.53 0.07 9.28 4 July 4.58 45.61 0.79 0.37 51.34 5 August 23.58 48.87 0.53 3.89 76.87 6 September 7.74 29.33 0.44 4.31 41.83 7 October 2.46 4.08 0.37 0.83 7.74 8 November 0.02 0.30 0.13 0.01 0.46 9 December 0.02 0.00 0.07 0.23 0.31 10 January 0.00 0.03 0.12 5.09 5.24 11 Feburary 0.57 0.00 0.15 4.16 4.87 12 March 6.26 0.10 0.08 1.68 8.12 Total 47.71 136.30 4.17 25.14 213.31 % Generation Lost 22% 64% 2% 12% 100%

6.5.6 Auxiliary Consumption and Transformation Losses

6.5.6.1 The analysis of auxiliary consumption data of past 14 years reveals that the auxiliary consumption of Dhalipur Power Station is around 0.27% of the Gross Generation. Similarly the transformation losses of past 14 years for which the data is available has been analysed are 1.66% of the gross generation. Both auxiliary and transformation losses together constitute around 1.94 % of the Gross Generation

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Table 112: Auxiliary and Transformation Losses – Dhalipur Power Station Sr. No Particulars Unit Value 1 Total Gross Generation 1998-12) MUs 3089.55 2 Total Aux. consumption (1998-12) MUs 8.49 3 Aux. consumption as a % of Gross Generation % 0.27% 4 Total Gross Generation (1998-12) MUs 3089.55 5 Total Transformation loss (1998-12) MUs 51.30 6 Transformation loss as a % of Gross Generation % 1.66% 7 Total Aux. and Transformation losses (1998-12) MUs 59.79 Total Aux. and Transformation losses as a % of 8 % 1.94% Gross Generation

6.5.6.2 UJVN Ltd. has taken steps to reduce the auxiliary consumption and transformation losses. Data of previous 4 years, which has already been submitted to Hon’ble UERC, as shown below, shows improvement in auxiliary and transformation losses.

Sr. No Year Transformation Auxiliary & line losses Consumption 1 FY 2010-11 0.7% 0.2% 2 FY 2009-10 1.2% 0.2% 3 FY 2008-09 1.5% 0.2% 4 FY 2007-08 1.3% 0.2% 5 Average 1.2% 0.2% 6.5.7 Inferences

6.5.7.1 Design Energy

The discharge data for Dhalipur Power station is available on 10 daily (average) basis for the period April 1994 to March 2012. The Design Energy is computed on the basis of the data for each 10 daily average discharge of the 90% dependable year. Correspondingly the Design Energy is calculated (refer to the earlier Table 106) to be 190.7 MU after accounting for uncontrollable energy loss of 5.01%. Design Energy was also calculated on the basis of maximum possible generation (refer earlier table 109) which comes to 182.23 MU.

Dhalipur Power Station is quite old Power Station and has been under operation since its commissioning in the year 1965. This long operation period has resulted

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into excessive wear and tear of the hydro mechanical and electro mechanical equipment, thereby causing breakdown of machines. The condition of these equipment is deteriorating with passage of time. UJVN Ltd. is taking proactive action by taking up comprehensive RMU of the Project for revival and life extension of the project.

Keeping in view the long operational life of the project, it is proposed that Design Energy for Dhalipur Power Station may be considered as 182.23 MU which is the Design Energy computed using the second approach mentioned earlier. However, after completion of the proposed RMU works of the Project, UJVN Ltd. shall approach the Commission to revise the Design Energy of the Project.

6.5.7.2 NAPAF

UERC has prescribed principle for Normal Plant Availability determination. Based on the principle given by UERC the annual plant availability has been calculated in the earlier table 106 which comes to 76.5%.

Based on actual running hours, reserve hours, forced outage hours and plant outage hours for last 11 years, plant average annual plant availability has been calculated in table no. 110 which comes to 82% and this may be taken as NAPAF for Dhalipur Power Station for base year of the control period.

6.5.7.3 Auxiliary Consumption and Transformation Losses

The auxiliary and transformation losses exceed the norms set by UERC for surface hydroelectric power generating stations with rotary excitation system by 1.24%. UJVN Limited proposes to take remedial measures during the proposed RMU to reduce these losses within the prescribed limits prescribed by the Commission.

6.5.8 Projections for the Control Period

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6.5.8.1 RMU works are proposed for the Dhalipur Power Station. The proposed RMU works are likely to result in (i) Extension of the Plant life by around 25 years (ii) Higher Plant Availability (iii) Increased operating efficiencies of plant. The RMU works for the plant is likely to be completed during the control period. The unit wise schedule for implementing RMU is as given below:

Name of Date of Start Date of Unit Commissioning Unit-1 01.10.14 30.06.15 Unit-2 01.10.15 30.06.16 Unit-3 01.10.16 30.06.17

6.5.9 Impact of RMU works on Energy Generation

6.5.9.1 The proposed RMU of Dhalipur Power Station is likely to result in increased availability of plant and refurbishment of turbines and generators leading to increased efficiencies. This could yield energy generation gains of the order of 15 % if the same level of water discharge is considered pre and post RMU. Primary purpose of RMU is life extension of the project apart from increase in generation. After RMU, generation will increase from 240 MU to 276 MU (as per DPR) subject to same water discharge.

6.5.10 Availability

6.5.10.1 The annual maintenance schedule and the RMU schedule proposed for Dhalipur Power Station under RMU works for the Control period is as given below:

FY2013-14

Unit No. Start Date End date Days Reasons 1 01-11-2013 15-12-2013 45 Annual Maintenance 2 16-12-2013 29-01-2014 45 Annual Maintenance 3 30-01-2014 15-03-2014 45 Annual Maintenance

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FY2014-15

Unit No. Start Date End date Days Reasons 1 01-10-2014 30-06-2015 273 RMU 2 01-11-2014 15-12-2014 45 Annual Maintenance 3 16-12-2014 29-01-2015 45 Annual Maintenance FY2015-16

Unit No. Start Date End date Days Reasons 1 16-12-2015 14-01-2016 30 Annual Maintenance 2 01-10-2015 30-06-2016 274 RMU 3 01-11-2015 15-12-2015 45 Annual Maintenance

6.5.10.2 After implementation of RMU works, full capacity of the plant is likely to be available for the entire year except during monsoon period and annual maintenance period. The plant availability during the control year considering maintenance schedule given above and forced outages expected (based on past data) during monsoon months is expected to be as given below:

Particulars Base Year FY 2013-14 FY 2014-15 FY 2015-16 Plant Availability (%) 82% 86.7% 73.9% 66.4%

6.5.10.3 The plant availability expected post RMU is likely to be around 87 %.

6.5.11 Auxiliary Consumption and Transformation losses

6.5.11.1 The normative auxiliary and transformation losses can be achieved after implementation of RMU works wherein energy efficient motors, starters, heating, air conditioning, illumination, power transformation and switching system would be adopted. The Dhalipur Power Station is expected to achieve normative loss level after completion of the RMU works.

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6.6 TECHNICAL REPORT OF KHODRI POWER STATION

6.6.1 Introduction

6.6.1.1 The Khodri Power Station with installed capacity of 120 MW (4X30 MW) is located on the downstream of the Chibro Power Station and was commissioned in the year 1984.The Power Station draws water through a 6 km long and 7.5 m diameter head race tunnel directly from the collection gallery of the Chibro Power Station through a siphon tunnel under river Tons. HRT ends at 21 m dia. and 46 m high surge tank where the water is conveyed and distributed to two no.5.5 m dia. and 85 m pressure shaft and subsequently by four 4.1 m dia. and 24 m long penstocks to the generating units.

6.6.1.2 Khodri Power Station operates in tandem mode with Chibro Power Station, which means both Power Stations are laid out for same design flow and no intermediate water storage.

6.6.1.3 The surface Power Station comprising 4 units of 30 MW each with Francis turbines of 43,600 HP output is located on the banks of river Yamuna in Distt. Sirmaur of H.P. State and the tail water flows in river Yamuna, upstream of the Dakpathar Barrage. The Power Station's design head is of 57.9 m.

6.6.1.4 The operation of Chibro and Khodri Power Stations is another engineering marvel. The tandem control scheme between Chibro and Khodri Power Stations is in operation since January, 1984 and is the first of its kind in the country which optimizes the utilization of water for generation besides maintaining the safety of both the plants in case of outages.

6.6.1.5 There are four generating units having vertical Francis turbine directly coupled with synchronous generator. The turbine output is 32.1 MW for a rated net head of 57.9 m. The generators are designed for a nominal output of 34 MVA with lagging power factor of 0.9 and class “B” insulation

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6.6.1.6 This Power Station was commissioned in the year 1984. Due to operations of machines for past 27 years in silt laden water, efficiency of machines has substantially decreased and availability of machines has been adversely affected, in spite of best and timely maintenance.

6.6.1.7 Though this Power Station has an installed capacity of 4x30 MW but due to constraints of water discharge limitations in HRT from collection gallery of Chibro maximum generating capacity is only 83 MW. As such while analyzing data for calculating Design Energy installed capacity of 83MW has been considered.

6.6.2 Determination of Design Energy

6.6.2.1 Khodri power Station is a run of the river Power Station. For computing the Design Energy two methodologies have been considered i.e. (i) on the basis of average of 10 daily discharges for calculation of NAPAF for Run-of-river type plant as per provision of UERC MYT 2011 Regulations “To be determined plant-wise, based on 10-day Design Energy data, moderated by past experience where available /relevant” and (ii) the maximum generation possible from the Khodri Power Station considering that there were no machine and other outages. Due to non-availability of 90% dependable 10 daily inflows pattern as approved in the DPR of the project, Design Energy and NAPAF have been calculated on the basis of available past reliable 10 daily discharge data.

(i) On the basis of Average of 10 daily discharges

Reliable 10 daily (average) discharge data for Khodri Power Station is available for the period April 1993 to March 2012 and the same has been considered for determination of 90% dependable year and Design Energy (this data is provided in the annexure 5). Reliable data for periods prior to April 1993 is not available with UJVN Limited. On considering average daily discharge data of the years for the same period, the 90% dependable year is found to be 2004-05, as given in table 113 below:

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Table 113: 90% Dependable year – Khodri Power Station Sl. No. 10 Daily Year % Discharge Dependability Average 1 129.06 1998-99 5.26 2 112.19 1995-96 10.53 3 107.07 1997-98 15.79 4 106.30 1996-97 21.05 5 103.75 1994-95 26.32 6 102.66 2002-03 31.58 7 100.01 1993-94 36.84 8 97.22 2003-04 42.11 9 97.05 2011-12 47.37 10 92.42 2005-06 52.63 11 92.28 1999-00 57.89 12 90.97 2010-11 63.16 13 88.05 2000-01 68.42 14 87.89 2008-09 73.68 15 87.34 2001-02 78.95 16 86.83 2006-07 84.21 17 84.62 2007-08 89.47 18 72.25 2004-05 94.74 19 66.25 2009-10 100.00 For computation of possible energy generation corresponding to the discharge considered, generator and turbine efficiencies have been considered as 0.969and 0.925 as per the past design records available with UJVN Limited. Design Energy estimation is sensitive to these assumptions. The plant has been in operation for past 28 years and it is quite possible that these parameters may have deteriorated from their designed values. In the absence of detailed technical study on the present efficiency levels of generator and turbine of Khodri Power Station, UJVN Limited for the present exercise is constrained to use these efficiency levels for computational purpose though the actual efficiency levels are expected to be much lower than the designed values. The energy generation corresponding to the 10 (ten) daily discharge for 2004-05 with 95% of the Installed capacity is given in the table below:

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Table 114: Discharge & Generation Data – Power Station Sr.no. Month Net Discharge Net Head Power Potential Energy (kWh) (cumecs) (meter) (kW) 1 April-I 45.1 57.9 22,960.9 55,10,625.1 2 April-II 48.9 57.9 24,895.6 59,74,935.0 3 April-III 53.0 57.9 26,982.9 64,75,900.9 4 May-I 60.0 57.9 30,546.7 73,31,208.5 5 May-II 77.1 57.9 39,252.5 94,20,603.0 6 May-III 74.4 57.9 37,859.4 99,94,881.0 7 June-I 58.0 57.9 29,528.5 70,86,834.9 8 June-II 84.2 57.9 42,867.2 1,02,88,129.3 9 June-III 67.0 57.9 34,110.5 81,86,516.2 10 July-I 90.8 57.9 46,227.3 1,10,94,562.2 11 July-II 78.0 57.9 39,710.7 95,30,571.1 12 July-III 94.3 57.9 47,995.3 1,26,70,772.1 13 Aug-I 148.6 57.9 75,654.0 1,81,56,959.8 14 Aug-II 167.1 57.9 85,072.6 2,04,17,415.8 15 Aug-III 155.5 57.9 79,143.7 2,08,93,944.3 16 Sept-I 125.7 57.9 63,995.3 1,53,58,881.9 17 Sept-III 103.7 57.9 52,794.9 1,26,70,772.1 18 Sept-III 76.7 57.9 39,048.9 93,71,728.2 19 Oct-I 63.3 57.9 32,226.8 77,34,425.0 20 Oct-II 83.3 57.9 42,409.0 1,01,78,161.2 21 Oct-III 54.1 57.9 27,538.3 72,70,115.1 22 Nov-I 43.1 57.9 21,942.7 52,66,251.5 23 Nov-II 36.5 57.9 18,582.6 44,59,818.5 24 Nov-III 35.6 57.9 18,124.4 43,49,850.4 25 Dec-I 39.0 57.9 19,855.4 47,65,285.5 26 Dec-II 36.4 57.9 18,531.7 44,47,599.8 27 Dec-III 34.7 57.9 17,680.1 46,67,536.1 28 Jan-I 35.7 57.9 18,175.3 43,62,069.1 29 Jan-II 33.7 57.9 17,157.1 41,17,695.5 30 Jan-III 37.1 57.9 18,883.4 49,85,221.8 31 Feb-I 45.9 57.9 23,368.2 56,08,374.5 32 Feb-II 66.7 57.9 33,957.8 81,49,860.2 33 Feb-III 60.9 57.9 30,992.2 59,50,497.6 34 March-I 77.9 57.9 39,659.8 95,18,352.4 35 March-II 102.5 57.9 52,183.9 1,25,24,147.9 36 March-III 99.9 57.9 50,864.9 1,34,28,330.3 Annual Energy Generation 32,22,18,833.7

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Table 115: Design Energy-Khodri Power Station Sr. No Particulars Unit Value 1 Generation Loss due to uncontrollable situation % 3.42% 2 Energy loss during monsoon and forced outages kWh 11029620.0 3 Design Energy kWh 311189213.7 4 Design Energy (MU) MUs 311.2 5 Plant Availability of FY 04-05 % 83.4 While determining Design Energy, a 3.42% (based on losses experienced during the operation of the plant) reduction in the energy generation has been considered. This reduction has been considered to take into account generation loss due to uncontrollable factors such as forced stoppages of machines and outages to prevent damage to the machines due to heavy silting during flash floods, flood passing and grid failure. These losses represent Hydrological risk and other uncontrollable risks which UJVN Limited cannot control in spite of its robust operating procedures. The figure of 3.42% has been determined considering generation loss on account of uncontrollable factors as a percentage of maximum possible generation without any unit and other outages on the basis of past data of the period 1999-00 to 2011-12. The details of these losses are provided in the table below:

Table 116: Uncontrollable Losses – Khodri Power Station Sr. No % losses B/D of Flushing & System Flood Total (5) Equipment Choking Condition Passing & (1) (2) (3) Any Other Reason (4) Gross losses as % of Max. 1 Gross Generation 1.74% 2.47% 0.36% 0.59% 5.16% Losses due to uncontrollable 2 factors (5)-(1) 3.42%

(ii) On the basis of Maximum possible plant generation

In view of the limited data size, UJVN Limited has also considered an alternate approach of computing Design Energy on the basis of actual gross generation

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and generation lost on account of various operational & Hydrological reasons for which the data is available since 1999-2012. The loss of generation (possible additional generation loss to UJVN Limited) is on account of (i) Equipment break down (ii) Flushing and Choking (iii) System Condition (iv) Flood passing and other reasons. UJVN Limited computes on a daily basis, the generation opportunity missed by it on account of these reasons. Thus the maximum energy that Khodri Power Station possibly could have generated (with 100% Unit availability and with no generation loss on account of any reason) is the gross generation by its Units and the generation loss suffered by it. This is an equally good approach for an existing plant for computing Design Energy when compared with the method of computing Design Energy on the basis of river discharge data as it is based on existing unit efficiencies instead of their design values, considers the impact of other project design related issues and also operational restrictions imposed on the plant. The maximum possible year wise generation has been computed in the table below:

Table 117: Year wise Maximum Possible Generation (MU) – Khodri Power Station Sr. no. Actual Gross Generation Maximum Year % Generation Loss (MU) Possible Dependabi (MU) Generation lity (MU) 1 408.57 10.81 419.38 2002-03 7.69 2 388.79 28.09 416.88 2003-04 15.38 3 367.41 40.49 407.90 2000-01 23.08 4 382.83 22.34 405.17 2011-12 30.77 5 378.94 25.83 404.76 2005-06 38.46 6 379.90 19.60 399.50 2008-09 46.15 7 361.78 37.14 398.92 2010-11 53.85 8 358.67 21.14 379.81 2001-02 61.54 9 365.35 9.30 374.65 1999-00 69.23 10 356.18 10.92 367.10 2006-07 76.92 11 354.72 10.38 365.10 2007-08 84.62 12 304.55 7.27 311.82 2004-05 92.31 13 275.87 11.53 287.41 2009-10 100.00

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On re-arranging the above data in the descending order and considering the 90% dependable year, the Design Energy for the Khodri Power Station is computed to be 301.15 MUs as given in the table below:

Table 118: Design Energy – Khodri Power Station Sr. No. Particular Unit Value 1 Dependable Year FY 2004-05 2 Maximum Possible Generation MUs 311.82 3 Plant Availability for FY 2004-05 % 83.44 4 Energy losses due to uncontrollable factors % 3.42% 5 Energy losses due to uncontrollable factors MUs 10.67 6 Design Energy (2)-(5) MUs 301.15

6.6.3 Determination of NAPAF

6.6.3.1 Actual average plant availability during the last 12 years is given in table below:

Table 119: Plant Availability during FY 2000 - 12 – Khodri Power Station Sr. No (1) Month (2) Total Reserve Forced Planned Maintenance Total hours Plant Running Outage Outage Annual Capital (max) Availability Hrs. of all (Hrs.) (4) (Hrs.) (5) Mainten Major (Hrs.) (8) % (9) the units ance repairs (Hrs.) (Col. 3+Col. (Hrs.) (3) (Hrs.) (6) (7) 4)/Col.8 1 April 13552 14275 207 3004 3522 34560 81% 2 May 18647 14024 135 1399 1507 35712 91% 3 June 20183 13381 137 859 0 34560 97% 4 July 25795 9312 395 210 0 35712 98% 5 August 27675 7794 106 137 0 35712 99% 6 Sept 25619 8814 90 37 0 34560 100% 7 Oct 17247 14647 355 993 2470 35712 89% 8 Nov 10591 15404 70 2889 5606 34560 75% 9 Dec 8569 15635 71 3841 7596 35712 68% 10 Jan 8057 16406 906 3290 7053 35712 69% 11 Feb 7603 14498 427 4059 5957 32544 68% 12 March 11640 14782 59 3025 6206 35712 74% Total 195178 158972 2958 23743 39917 420768 84%

6.6.3.2 The Khodri Power Station experiences forced shut downs during the monsoon period. The reasons for these forced shut downs have been provided in the section below. The average plant availability during last 12 years is around 84%.

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6.6.4 Special Circumstances and Abnormal Operating Conditions

6.6.4.1 Since, its commissioning Khodri Power Station operates on base load during Monsoon period and as a peaking station during non-monsoon period when discharge in the river reduces and Power Station has to be run on partial Capacity. But due to silting of Ichari Dam the peaking capacity has also reduced and Power Station meets evening and morning peaks during lean discharge period as per the requirement of SLDC.

6.6.4.2 Study of the available inflow data revealed that the maximum capacity can be generated between May to September and partially between October to April. Lean discharge period is again utilised for planned annual or capital maintenance.

6.6.4.3 Annual loss of energy during Monsoon due to flushing and choking, over the period 1999-12 has been calculated in the table 116 & 120 below, which is around 2.5% of the gross generation and 48% of the total generation loss. Such annual loss should therefore be appropriately accounted for while computing Design Energy and plant availability.

6.6.5 Plant Outages and Breakdowns

6.6.5.1 Apart from above facts, when flood recedes lot of silt having substantial quartzite particles are lodged in cavities and caves on both banks of river which gets dislodged when level of river starts rising as a result of snow melting during summer season and is carried to the machines through water conductor system causing severe damage to under water parts and frequent plant outages which becomes beyond control of UJVN Limited

6.6.5.2 The forced outage data for the period 1999-2012 has revealed that 34% of the total energy loss is on this account. The table below provides the details.

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Table 120: % Generation Loss on account of various Factors – Khodri Power Station Sr. No. Month↓ B/D of Flushing & System Flood Total Equipment Choking Condition passing & (in MU) (in MU) (in MU) & Grid fail Any Other (in MU) Reasons (in MU) 1 April 0.00 0.74 0.30 0.11 1.14 2 May 8.00 1.19 9.05 0.00 18.24 3 June 3.76 11.62 0.19 1.23 16.79 4 July 19.88 43.01 2.60 1.59 67.08 5 August 31.09 45.98 5.43 16.90 99.40 6 September 18.51 17.83 0.08 6.43 42.85 7 October 0.91 0.50 0.06 2.23 3.70 8 November 0.00 0.42 0.00 0.41 0.83 9 December 0.00 0.00 0.00 0.00 0.00 10 January 3.64 0.00 0.02 0.26 3.91 11 Feburary 0.00 0.00 0.16 0.00 0.17 12 March 0.00 0.73 0.00 0.00 0.73 Total 85.80 122.01 17.89 29.14 254.85 Generation Lost 34% 48% 7% 11% 100%

6.6.6 Auxiliary Consumption and Transformation Losses

6.6.6.1 The analysis of auxiliary consumption of past 13 years reveals that the auxiliary consumption of Khodri Power Station is around 0.2% of the Gross Generation. Similarly the transformation losses of past 13 years for which the data is available has been analysed. The transformation losses are 0.5% of the gross generation. Both auxiliary and transformation losses together constitute around 0.7% of the Gross Generation.

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Table 121: Auxiliary and Transformation Losses – Khodri Power Station Sr. No Particulars Unit Value 1 Total Gross Generation (1999-12) MUs 4683.56 2 Total Aux. consumption (1999-12) MUs 10.96 3 Aux. consumption as a % of Gross Generation % 0.2% 4 Total Gross Generation (1999-12) MUs 4683.56 5 Total Transformation loss (1999-12) MUs 23.36 6 Transformation loss as a % of Gross Generation % 0.5% 7 Total Aux. and Transformation losses (1999-12) MUs 34.32 Total Aux. and Transformation losses as a % of 8 % 0.7% Gross Generation

6.6.6.2 UJVN Ltd. has taken steps to reduce the auxiliary consumption and transformation losses. Data of previous 4 years, which has already been submitted to Hon’ble UERC, as shown below, shows improvement in auxiliary and transformation losses.

Sr. No Year Transformation Auxiliary & line losses Consumption 1 FY 2010-11 0.03% 0.22% 2 FY 2009-10 0.16% 0.29% 3 FY 2008-09 0.37% 0.23% 4 FY 2007-08 0.34% 0.26% 5 Average 0.23% 0.25% 6.6.7 Inferences

6.6.7.1 Design Energy

The discharge data for Khodri Power Station is available on 10 daily (average) basis for the period April 1993 to March 2012. The Design Energy computed on the basis of data for each 10 daily average discharge of 90% dependable year. Correspondingly the Design Energy is calculated (refer to the earlier table 115) to be 311.19 MU after accounting for uncontrollable energy loss of 3.42%.

Design Energy was also calculated based on maximum possible generation (refer to the earlier table 118) which comes to 301.15 MU.

Khodri Power Station is quite old Power Station and has been under operation since its commissioning in the year 1984. This long operation period has resulted

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Keeping in view the long operational life of the project, it is proposed that Design Energy for Khodri Power Station may be considered as 301.15 MU which is the Design Energy computed using the second approach mentioned earlier. However, after completion of the proposed RMU works of the Project, UJVN Ltd. shall approach the Commission to revise the Design Energy of the Project.

6.6.7.2 NAPAF

UERC has prescribed principle for determination of NAPAF. Based on the principle given by UERC the annual plant availability has been calculated in the table no 115 which comes to 83.4%.

Based on actual running hours, reserve hours, forced outage hours and plant outage hours for last 12 years average annual plant availability has been calculated in table no. 119 which comes to 84% and this may be considered as NAPAF for Khodri Power Station for control period.

6.6.7.3 Auxiliary Consumption and Transformation Losses

As explained in the earlier section, these losses are within the limit of 1% prescribed by UERC for Surface hydroelectric power generating stations with static excitation system.

6.6.8 Projections for the control period

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6.6.8.1 RMU works are proposed for the Khodri Power Station. The proposed RMU works are likely to result in (i) Extension of the Plant life by around 25 years (ii) Higher Plant Availability (iii) Increased operating efficiencies of plant. The RMU works for the plant is likely to be completed during the control period. The unit wise schedule for implementing RMU is as given below:

Name of Date of Start Date of Unit Commissioning Unit-1 01.11.15 31.03.17 Unit-2 01.06.17 31.03.18 Unit-3 01.06.18 31.03.19 Unit-4 01.06.19 31.03.20

6.6.9 Impact of RMU works on Energy Generation

6.6.9.1 The proposed RMU of Khodri Power Station is likely to result in increased plant availability and refurbishment of turbines and generators is likely to lead to increased efficiencies. These measures could yield energy gains of the order of 9.4 % if the same level of power discharge is considered pre and post RMU. Primary purpose of RMU is life extension of the project apart from increase in generation. After RMU, generation will increase from 406 MU to 444 MU (as per DPR) subject to same water discharge.

6.6.10 Availability

6.6.10.1 The annual maintenance schedule and the RMU schedule proposed for Khodri Power Station under RMU works for the Control period is as given below:

2013-14

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6.6.10.2 After implementation of RMU works full capacity of the plant is likely to be available for the entire year except for monsoon and annual maintenance. The plant availability during the control year considering maintenance schedule given above and forced outages expected (based on past data) during monsoon months is expected to be as given below:

Particulars Base Year FY 2013-14 FY 2014-15 FY 2015-16 Plant Availability (%) 84% 88.5% 88.5% 80.9%

6.6.10.3 The plant availability expected post RMU is likely to be around 88 %.

6.6.11 Auxiliary Consumption and Transformation losses

6.6.11.1 As stated above the auxiliary and transformation losses are within the limits prescribed by the Commission. During the control period these are expected to be within the limits prescribed by the Commission.

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6.7 TECHNICAL REPORT OF KULHAL POWER STATION

6.7.1 Introduction

6.7.1.1 The Kulhal Power Station with an installed capacity of 30 MW (3X10 MW) is located on the downstream of the Asan Barrage at a distance of 4.0 km on the power channel which takes off from the Asan Barrage. The Power Station was commissioned in the year 1975. The surface Power Station comprising 3 units of 10 MW each with Kaplan turbines is located on the power channel which terminates in 39.2 m wide and 6.9 m deep fore bay. There are three 30 m long and 4.5 m dia. steel lined penstocks, one for each unit. In case of tripping of machines full discharge gets bye-passed through a 21m wide gated bye pass channel. The water from the tail race flows towards Khara Power Station in UP. The Kulhal Power Station is a low head scheme located on power channel with a design head of 18 m and design discharge of 198 cum.

6.7.1.2 There are three generating units having vertical Kaplan turbine directly coupled with synchronous generator. The turbine output is 10.4 MW for a rated net head of 18 m. The generators are designed for a nominal output of 11.1 MVA with lagging power factor of 0.9 and class “B” insulation.

6.7.1.3 This Power Station was commissioned in the year 1975. Due to continuous operations of machines for past 36 years, efficiency of machines has substantially decreased and availability of machines has been adversely affected even in spite of best and timely maintenance and adoption of effective operational strategy.

6.7.2 Determination of Design Energy

6.7.2.1 Kulhal Power Station is a run of the river plant. For computing the Design Energy two methodologies have been considered i.e. (i) on the basis of average of 10 daily discharges for calculation of NAPAF for Run-of-river type plant as per provision of UERC MYT 2011 Regulations “To be determined plant-wise, based on 10-day Design

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Energy data, moderated by past experience where available /relevant” and (ii) the maximum generation possible from the Kulhal Power Station considering that there were no machine and other outages. Due to non-availability of 90% dependable 10 daily inflows pattern as approved in the DPR of the project, Design Energy and NAPAF have been calculated on the basis of available past reliable 10 daily discharge data.

(i) On the basis of Average of 10 daily discharges

Reliable 10 daily (average) discharge data for Kulhal Power Station is available for the period April 2001 to March 2012 and the same has been considered for determination of 90% dependable year and Design Energy (this data is provided in the annexure 6). Reliable data for periods prior to April 2001 is not available with UJVN Limited. On considering the average daily discharge data of the years for the same period, the 90% dependable year is found to be 2001-02, as given in the table below:

Table 122: 90% dependable year – Kulhal Power Station Sl. No. 10 Daily Year % Discharge Dependability Average 1 124.04 02-03 9.09 2 121.52 05-06 18.18 3 118.63 11-12 27.27 4 117.07 03-04 36.36 5 115.02 08-09 45.45 6 113.81 06-07 54.55 7 113.49 07-08 63.64 8 109.10 10-11 72.73 9 101.01 04-05 81.82 10 98.97 01-02 90.91 11 86.17 09-10 100.00 For computation of possible energy generation corresponding to the discharge considered, generator and turbine efficiencies have been considered as 0.968 (at 100% load) and 0.91 as per the past design records available with UJVN Limited. Design Energy estimation is sensitive to these

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assumptions. The plant has been in operation for 36 years and it is quite possible that these parameters may have deteriorated from their designed values. In the absence of detailed technical study on the present efficiency levels of generator and turbine of Kulhal Power Station, UJVN Limited for the present exercise is constrained to use these efficiency levels for computational purpose though the actual efficiency levels are expected to be much lower than designed values.

The energy generation corresponding to the 10 (ten) daily discharge for 2001-02 with 95% of the Installed capacity is given in the table below:

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Table 123: Discharge & Generation Data – Kulhal Power Station Sr.no. Month Net Discharge Net Head Power Potential Energy (kWh) (cumecs) (meter) (kW)

1 April-I 60.6 18.0 9,507.4 22,81,784.2 2 April-II 73.1 18.0 11,474.9 27,53,965.9 3 April-III 84.1 18.0 13,206.8 31,69,630.4 4 May-I 95.1 18.0 14,924.3 35,81,828.6 5 May-II 113.2 18.0 17,539.6 42,09,509.9 6 May-III 102.4 18.0 15,863.1 41,87,861.8 7 June-I 109.7 18.0 16,994.7 40,78,728.7 8 June-II 140.3 18.0 21,749.0 52,19,753.6 9 June-III 151.3 18.0 23,538.4 56,49,224.0 10 July-I 173.2 18.0 26,944.4 64,66,660.7 11 July-II 158.2 18.0 24,603.0 59,04,717.3 12 July-III 152.7 18.0 23,755.1 62,71,345.0 13 Aug-I 158.3 18.0 24,621.0 59,09,047.7 14 Aug-II 149.8 18.0 23,303.6 55,92,854.2 15 Aug-III 169.8 18.0 26,419.3 69,74,698.1 16 Sept-I 178.4 18.0 27,750.9 66,60,221.9 17 Sept-III 159.5 18.0 24,816.6 59,55,972.8 18 Sept-III 129.3 18.0 20,045.4 48,10,895.0 19 Oct-I 109.7 18.0 17,007.9 40,81,890.4 20 Oct-II 91.3 18.0 14,340.9 34,41,816.8 21 Oct-III 83.6 18.0 13,121.5 34,64,084.6 22 Nov-I 81.3 18.0 12,756.5 30,61,569.7 23 Nov-II 66.7 18.0 10,464.9 25,11,582.8 24 Nov-III 63.5 18.0 9,962.6 23,91,013.0 25 Dec-I 59.0 18.0 9,256.6 22,21,574.7 26 Dec-II 59.6 18.0 9,351.7 22,44,407.6 27 Dec-III 56.0 18.0 8,793.8 23,21,572.3 28 Jan-I 50.3 18.0 7,904.2 18,97,015.7 29 Jan-II 50.9 18.0 7,995.3 19,18,869.0 30 Jan-III 50.8 18.0 7,978.9 21,06,430.5 31 Feb-I 58.4 18.0 9,162.4 21,98,967.8 32 Feb-II 81.0 18.0 12,716.4 30,51,924.1 33 Feb-III 1.9 18.0 295.3 56,705.5 34 March-I - 18.0 - - 35 March-II - 18.0 - - 36 March-III 105.2 18.0 16,309.6 43,05,736.0 Annual Energy Generation 13,09,53,860.0

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Table 124: Design Energy-Kulhal Power Station Sr. No Particulars Unit Value 1 Generation Loss due to uncontrollable situation % 5.35% 2 Energy loss during monsoon and forced outages kWh 70,09,640.9 3 Design Energy kWh 12,39,44,219.1 4 Design Energy (MU) MUs 123.94 5 Plant Availability of FY 01-02 % 86.1 While determining Design Energy, a 5.35% (based on losses experienced during the operation of the plant) reduction in the energy generation has been considered. This reduction has been considered to take into account generation loss due to uncontrollable factors such as forced stoppages of machines and outages to prevent damage to the machines due to heavy silting during flash floods, flood passing and grid failure etc. These losses represent Hydrological risk and other uncontrollable risks which UJVN Limited cannot control in spite of its robust operating procedures. The figure of 5.35% has been determined considering generation loss on account of uncontrollable factors as a percentage of maximum possible generation without any unit and other outages on the basis of past data of the period 2001-12. The details of these losses are provided in the table below:

Table 125: Uncontrollable Losses – Kulhal Power Station Sr. No % losses B/D of Flushing & System Flood Total (5) Equipment Choking Condition Passing & (1) (2) (3) Any Other Reason (4) Gross losses as % of Max. 1 Gross Generation 0.49% 3.01% 0.18% 2.20% 5.84% Losses due to uncontrollable 2 factors (5)-(1) 5.35%

(ii) On the basis of Maximum possible plant generation

In view of the limited data size, UJVN Limited has also considered an alternate option of computing Design Energy on the basis of actual gross generation and generation lost on account of various operational & Hydrological reasons

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for which the data is available since 2001-02. The loss of generation (possible additional generation loss to UJVN Limited) is on account of (i) Equipment break down (ii) Flushing and Choking (iii) System Condition (iv) Flood passing and other reasons. UJVN Limited computes on a daily basis, the generation opportunity missed by it on account of these reasons. Thus the maximum energy that Kulhal Power Station possibly could have generated (with 100% Unit availability and with no generation loss on account of any reason) is the gross generation by its Units and the generation loss suffered by it. This is an equally good option for an existing plant for computing Design Energy when compared with the method of computing Design Energy on the basis of river discharge data as it is based on existing unit efficiencies instead of their design values, considers the impact of other project design related issues and also operational restrictions imposed on the plant. The maximum possible year wise generation has been computed in the table below:

Table 126: Year wise Maximum Possible Generation (MU) – Kulhal Power Station Sr. no. Actual Gross Generation Maximum Year % Generation Loss (MU) Possible Dependabi (MU) Generation lity (MU) 1 160.94 10.04 170.98 2005-06 9.09 2 157.83 10.60 168.43 2011-12 18.18 3 163.70 3.83 167.53 2002-03 27.27 4 155.33 10.04 165.37 2003-04 36.36 5 142.53 19.00 161.53 2010-11 45.45 6 143.69 15.77 159.46 2008-09 54.55 7 149.76 5.09 154.85 2007-08 63.64 8 148.67 3.62 152.29 2006-07 72.73 9 124.89 10.49 135.38 2001-02 81.82 10 128.82 5.95 134.77 2004-05 90.91 11 112.61 4.10 116.71 2009-10 100.00 On re-arranging the above data in the descending order and considering the 90% dependable year, the Design Energy for the Kulhal Power Station is computed to be 127.55 MUs as given in the table below:

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Table 127: Design Energy – Kulhal Power Station Sr. No. Particular Unit Value 1 Dependable Year FY 2004-05 2 Maximum Possible Generation MUs 134.77 3 Plant Availability for FY 2004-05 % 91.00 4 Energy losses due to uncontrollable factors % 5.35% 5 Energy losses due to uncontrollable factors MUs 7.21 6 Design Energy (2)-(5) MUs 127.55

6.7.3 Determination of NAPAF

6.7.3.1 Actual average plant availability during the last 11 years is given in the table below:

Table 128: Plant Availability during FY 2001- 12 – Kulhal Power Station Sr. No (1) Month (2) Total Reserve Forced Planned Maintenance Total hours Plant Running Outage Outage Annual Capital (max) Availability Hrs. of all (Hrs.) (4) (Hrs.) (5) Mainten Major (Hrs.) (8) % (9) the units ance repairs (Hrs.) (Col. 3+Col. (Hrs.) (3) (Hrs.) (6) (7) 4)/Col.8 1 April 13604 8524 615 1017 0 23760 93% 2 May 16689 7773 90 0 0 24552 100% 3 June 17445 5993 322 0 0 23760 99% 4 July 21867 2149 536 0 0 24552 98% 5 August 22400 2068 84 0 0 24552 100% 6 Sept 21734 2012 9 5 0 23760 100% 7 Oct 18780 5513 130 129 0 24552 99% 8 Nov 13044 6013 0 4703 0 23760 80% 9 Dec 10360 7023 605 6564 0 24552 71% 10 Jan 9616 7831 518 6587 0 24552 71% 11 Feb 7872 8291 626 5603 0 22392 72% 12 March 11734 5401 763 6654 0 24552 70% Total 185145 68591 4298 31262 0 289296 88%

6.7.3.2 The availability plant availability during this period is around 88%.

6.7.4 Special Circumstances and Abnormal Operating Conditions

6.7.4.1 Since its commissioning this Power Station operates on base load during monsoon period and as a peaking station during non- monsoon period when discharge in the river reduces and Power Station has to be run on partial load. But due to silting of reservoir of Asan Barrage, the peaking capacity has also reduced and Power Station

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meets evening and morning peaks during lean discharge period as per the requirement of SLDC.

6.7.4.2 Study of the available inflow data revealed that the maximum capacity that can be generated between May to September and partially between October to April. Lean discharge period is again utilised for planned annual or capital maintenance.

Annual loss of energy during Monsoon due to flushing and choking over the period 2001-12 has been calculated in the table 125 and 129, which is around 3% of the gross generation and 52% of the total generation loss. Such annual loss should therefore be appropriately accounted for while computing Design Energy and plant availability.

6.7.5 Plant Outages and Breakdowns

6.7.5.1 The forced outage data for the period 2001-2012 has revealed that 8% of the total energy loss is on this account. The table below provides the details.

Table 129: % Generation Loss on account of various Factors – Kulhal Power Station Sr. No. Month↓ B/D of Flushing & System Flood Total Equipment Choking Condition passing & (in MU) (in MU) (in MU) & Grid fail Any Other (in MU) Reasons (in MU) 1 April 0.00 0.00 0.81 0.20 1.01 2 May 0.15 0.09 0.39 0.00 0.63 3 June 3.07 2.28 0.30 0.00 5.89 4 July 4.25 17.87 0.46 2.99 28.38 5 August 0.34 15.53 0.34 9.08 30.32 6 September 0.09 12.00 0.40 15.75 26.09 7 October 0.00 2.42 0.05 4.24 1.31 8 November 0.00 0.56 0.03 0.64 0.12 9 December 0.00 0.08 0.07 0.00 0.07 10 January 0.00 0.00 0.04 0.01 0.07 11 Feburary 0.00 0.00 0.09 2.72 2.81 12 March 0.32 0.03 0.05 1.47 1.85 Total 8.22 50.85 3.04 37.08 98.54 % Generation Lost 8% 52% 3% 38% 100% 6.7.6 Auxiliary Consumption and Transformation Losses

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6.7.6.1 The analysis of auxiliary consumption data of past 12 years reveals that the auxiliary consumption of Kulhal Power Station is around 0.3% of the Gross Generation. Similarly the transformation losses of past 12 years for which the data is available has been analysed. The transformation losses are 2.8% of the gross generation. Both auxiliary consumption and transformation losses together constitute around 3.1 % of the Gross Generation.

Table 130: Auxiliary and Transformation Losses – Kulhal Power Station Sr. No. Particulars Unit Value 1 Total Gross Generation (2000-12) MUs 1733.89 2 Total Aux. consumption (2000-12) MUs 5.09 3 Aux. consumption as a % of Gross Generation % 0.3% 4 Total Gross Generation (2000-12) MUs 1733.89 5 Total Transformation loss (2000-12) MUs 48.14 6 Transformation loss as a % of Gross Generation % 2.8% 7 Total Aux. and Transformation losses (2000-12) MUs 53.23 Total Aux. and Transformation losses as a % of 8 % 3.1% Gross Generation

6.7.6.2 UJVN Ltd. has taken steps to reduce the auxiliary consumption and transformation losses. Data of previous 4 years, which has already been submitted to Hon’ble UERC, as shown below, shows improvement in auxiliary consumption and transformation losses.

Sr. No Year Transformation Auxiliary & line losses Consumption 1 FY 2010-11 4.3% 0.3% 2 FY 2009-10 1.5% 0.4% 3 FY 2008-09 2.5% 0.3% 4 FY 2007-08 1.3% 0.3% 5 Average 2.4% 0.3% 6.7.7 Inferences

6.7.7.1 Design Energy

The discharge data for Kulhal Power Station is available on 10 daily (average) basis for the period April 2001 to March 2012. The data for each 10 daily average discharge of the year is selected on the basis of 90% dependable year.

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Correspondingly the Design Energy is calculated (refer the earlier Table 124) to be 123.9 MU after accounting for uncontrollable energy loss of 5.4%.

Design Energy was also calculated based on maximum possible generation (refer the earlier table 127) which comes to 127.55 MU.

Kulhal Power Station is quite old Power Station and has been under operation since its commissioning in the year 1975. This long operation period has resulted into excessive wear and tear of the hydro mechanical and electro mechanical equipment, thereby causing breakdown of machines. The condition of these equipment is deteriorating with passage of time. UJVN Ltd. is taking proactive action by taking up comprehensive RMU of the Project for revival and life extension of the project.

Keeping in view the long operational life of the project, it is proposed that Design Energy for Kulhal Power Station may be considered as 127.55 MU which is the Design Energy computed using the second approach mentioned earlier. However, after completion of the proposed RMU works of the Project, UJVN Ltd. shall approach the Commission to revise the Design Energy of the Project.

6.7.7.2 NAPAF

UERC has prescribed principle for its determination of Normative Plant Availability for run of the river plant. Based on the principle prescribed by UERC, the annual plant availability has been calculated in the earlier tables 124 & 127 which comes to 86.1% (FY01-02) and 91 %( 2004-05) respectively.

Based on actual running hours, reserve hours, forced outage hours and plant outage hours for last 12 years average annual Plant Availability has been calculated in the table 127 which comes to 88% and this may be taken as NAPAF for Kulhal Power Station for base year of the control period.

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6.7.7.3 Auxiliary Consumption and Transformation Losses

The auxiliary and transformation losses exceed the norms set by UERC for surface hydroelectric power generating stations with rotating excitation system by 2.4%. UJVN Limited proposes to take remedial measures during the proposed RMU to reduce these losses within the prescribed limits prescribed by the Commission.

6.7.8 Projections for the Control Period

6.7.8.1 RMU works are proposed for the Kulhal Power Station. The proposed RMU works are likely to result in (i) Extension of the Plant life by around 25 years (ii) Higher Plant Availability (iii) Increased operating efficiencies of plant. The RMU works for the plant is likely to be completed during the control period. The unit wise schedule for implementing RMU is as given below:

Name of Date of Start Date of Unit Commissioning Unit-1 01.10.14 30.06.15 Unit-2 01.10.15 30.06.16 Unit-3 01.10.16 30.06.17

6.7.9 Impact of RMU works on Energy Generation

6.7.9.1 The proposed RMU of Kulhal Power Station is likely to result in increased plant availability and refurbishment of turbines and generators is likely to result in increased efficiencies. These measures could yield energy gains of the order of 26 % if the same level of waterdischarge is considered pre and post RMU. Primary purpose of RMU is life extension of the project apart from increase in generation. After RMU, generation will increase from 145 MU to 183 MU (as per DPR) subject to same water discharge

6.7.10 Availability

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6.7.10.1 The annual maintenance schedule and the RMU schedule proposed for Kulhal Power Station under RMU works for the Control period is as given below:

FY2013-14

Unit No. Start Date End date Days Reasons 1 01-11-2013 15-12-2013 45 Annual Maintenance 2 16-12-2013 29-01-2014 45 Annual Maintenance \ 3 30-01-2014 15-03-2014 45 Annual Maintenance

FY2014-15

Unit No. Start Date End date Days Reasons 1 01-10-2014 30-06-2015 273 RMU 2 01-11-2014 15-12-2014 45 Annual Maintenance 3 16-12-2014 29-01-2015 45 Annual Maintenance FY2015-16

Unit No. Start Date End date Days Reasons 1 16-12-2015 14-01-2016 30 Annual Maintenance 2 01-10-2015 30-06-2016 274 RMU 3 01-11-2015 15-12-2015 45 Annual Maintenance

6.7.10.2 After implementation of RMU works full capacity of the plant is likely to be available for the entire period except monsoon period and annual maintenance period. The plant availability during the control year considering maintenance schedule given above and forced outages expected (based on past data) during monsoon months is expected to be as given below:

Particulars Base Year FY 2013-14 FY 2014-15 FY 2015-16 Plant Availability (%) 88% 86.7% 73.6% 66.8%

6.7.10.3 The plant availability expected post RMU is likely to be around 90 %.

6.7.11 Auxiliary Consumption and Transformation losses

6.7.11.1 The normative auxiliary and transformation losses can be achieved after implementation of RMU works wherein energy efficient motors, starters, heating, air conditioning, illumination, power transformation and switching system would

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be adopted. The Kulhal Power Station is expected to achieve normative auxiliary consumption and transformation loss level after completion of the RMU works.

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6.8 TECHNICAL REPORT OF CHILLA POWER STATION

6.8.1 Introduction

6.8.1.1 Chilla Hydro Power Station with an installed capacity of 144 MW (4x36 MW) is a run of river scheme constructed on river Ganga 5 Km upstream of holy town Hardwar and situated in District Pauri Garhwal of Uttarakhand state. The scheme consists of a 312 m long, 11.5 m high gated diversion barrage at Pashulok, about 4 Km downstream of holy town Rishikesh. The river inflows are diverted via head regulator with silt ejector constructed 500 m downstream in the bed of lined power channel and 14.3 km long and 565 cumecs capacity power channel, which ends at fore bay of Chilla Power Station where the water is fed to the generating units through 4 nos. 4.6 m dia. and 55 m long steel lined penstocks.

6.8.1.2 There are four generating units having vertical Kaplan turbines directly coupled with synchronous generator. The turbine output is 36 MW for a rated net head of 32.5 m. The generators are designed for a nominal output of 36 MW with lagging power factor of 0.9 and class “B” insulation.

6.8.1.3 This Power Station was commissioned in the year 1980-81. Due to operations of machines for past 32 years in highly abrasive silt laden water, efficiency of machines has substantially decreased and availability of machines has been adversely affected even in spite of best and timely maintenance.

6.8.2 Determination of Design Energy

6.8.2.1 Chilla Power Station is a run of the river plant. For computing the Design Energy, two methodologies have been considered i.e. (i) on the basis of average of 10 daily discharges for calculation of NAPAF for Run-of-river type plant as per provision of UERC MYT 2011 Regulations “To be determined plant-wise, based on 10-day Design Energy data, moderated by past experience where available /relevant” and (ii) the maximum generation possible from the Chilla Power Station considering that there

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were no machine and other outages. Due to non-availability of 90% dependable 10 daily inflows pattern as approved in the DPR of the project, Design energy and NAPAF have been calculated on the basis of available past reliable 10 daily discharge data.

(i) On the basis of average of 10 daily discharges

Reliable 10 daily (average) discharge data for Chilla Power Station is available only for the period April 2002 to March 2012 and the same has been considered for determination of Design Energy (this data is provided in the annexure 7). Reliable data for periods prior to April 2002 is not available with UJVN limited. On considering the yearly average daily discharge of the same period, the 90% dependable year is found to be 2005-06, as given in the table below:

Table 131: 90% dependable year – Chilla Power Station Sr. No. 10 Daily Year % Average Dependability Discharge 1 500.61 11-12 10.00 2 432.68 07-08 20.00 3 425.38 08-09 30.00 4 424.59 10-11 40.00 5 399.43 09-10 50.00 6 393.49 06-07 60.00 7 374.05 04-05 70.00 8 373.43 03-04 80.00 9 346.28 05-06 90.00 10 338.89 02-03 100.00 For computation of possible energy generation corresponding to the discharge considered, generator and turbine efficiencies have been considered as 0.97 and 0.92 as per the past design records available with UJVN Limited. Design Energy estimation is sensitive to these assumptions. The plant has been in operation for 32 years and it is quite possible that these parameters may have deteriorated from their design values. In the absence of detailed technical study on the present efficiency levels of

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generator and turbine of Chilla Power Station, UJVN Limited for the present exercise is constrained to use these efficiency levels for computational purpose though the actual efficiency levels are expected to be lower.

The energy generation corresponding to the 10 (ten) daily discharge for 2005-06 with 95% of the Installed capacity is given in the table below:

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Table 132: Discharge & Generation Data – Chilla Power Station Sr.no. Month Net Discharge Net Head Power Potential Energy (kWh) (cumecs) (meter) (kW) 1 April-I 253.4 32.5 72,409.4 1,73,78,255.3 2 April-II 273.0 32.5 78,010.1 1,89,82,463.5 3 April-III 350.6 32.5 1,00,175.3 2,43,75,999.0 4 May-I 408.5 32.5 1,16,729.4 2,84,04,162.4 5 May-II 429.5 32.5 1,22,730.2 2,98,64,351.9 6 May-III 376.0 32.5 1,07,442.5 2,61,44,345.3 7 June-I 417.2 32.5 1,19,215.5 2,90,09,098.1 8 June-II 477.0 32.5 1,36,303.4 3,31,67,161.5 9 June-III 414.6 32.5 1,18,472.5 2,88,28,312.7 10 July-I 426.7 32.5 1,21,930.1 2,96,69,660.0 11 July-II 471.2 32.5 1,34,646.0 3,27,63,871.1 12 July-III 517.6 32.5 1,47,915.3 3,32,88,000.0 13 Aug-I 537.5 32.5 1,53,591.4 3,32,88,000.0 14 Aug-II 534.4 32.5 1,52,705.5 3,32,88,000.0 15 Aug-III 549.1 32.5 1,56,903.5 3,32,88,000.0 16 Sept-I 558.9 32.5 1,59,706.4 3,32,88,000.0 17 Sept-III 520.3 32.5 1,48,676.4 3,32,88,000.0 18 Sept-III 539.7 32.5 1,54,220.0 3,32,88,000.0 19 Oct-I 556.9 32.5 1,59,134.9 3,32,88,000.0 20 Oct-II 547.4 32.5 1,56,420.3 3,32,88,000.0 21 Oct-III 476.1 32.5 1,36,043.6 3,31,03,949.8 22 Nov-I 295.7 32.5 84,496.7 2,05,60,858.8 23 Nov-II 244.4 32.5 69,837.6 1,69,93,824.5 24 Nov-III 208.6 32.5 59,607.7 1,45,04,549.0 25 Dec-I 188.0 32.5 53,721.3 1,30,72,172.7 26 Dec-II 180.5 32.5 51,578.1 1,25,50,676.4 27 Dec-III 183.4 32.5 52,396.4 1,27,49,793.2 28 Jan-I 179.7 32.5 51,349.5 1,24,95,050.1 29 Jan-II 181.4 32.5 51,835.3 1,26,13,256.0 30 Jan-III 173.4 32.5 49,538.9 1,20,54,464.8 31 Feb-I 170.0 32.5 48,577.7 1,18,20,581.7 32 Feb-II 165.7 32.5 47,349.0 1,15,21,590.5 33 Feb-III 164.8 32.5 47,077.5 1,14,55,534.3 34 March-I 160.6 32.5 45,891.7 1,11,66,973.0 35 March-II 164.1 32.5 46,891.8 1,14,10,337.9 36 March-III 124.5 32.5 35,589.0 86,59,998.3 Annual Energy Generation 82,49,13,291.7

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Table 133: Design Energy: Chilla Power Station Sr. No Particulars Unit Value 1 Generation Loss due to uncontrollable situation % 5.6% 2 Energy loss during monsoon and forced outages kWh 45964112.2 3 Design Energy kWh 778949179.6 4 Design Energy (MU) MUs 778.9 5 Plant Availability of 05-06 % 76.4 While determining Design Energy, a 5.6% (based on losses experienced during the operation of the plant) reduction in the energy generation has been considered. This reduction has been considered to take into account generation loss due to uncontrollable factors such as forced stoppages of machines and outages to prevent damage to the machines due to heavy silting during flash floods, flood passing and grid failure. These losses represent hydrological risk and other uncontrollable risks which UJVN Limited cannot control in spite of robust operating procedures. The figure of 5.6% has been determined considering generation loss on account of uncontrollable factors as a percentage of maximum possible generation without any unit and other outages on the basis of past data of the period 2002-03 to 2011- 12. The details of the losses are provided in the table below:

Table 134: Uncontrollable Losses – Chilla Power Station

Sr. No % losses B/D of Flushing & System Flood Total (5) Equipment Choking Condition Passing & (1) (2) (3) Any Other Reason (4) Gross losses as % of Max 1 Gross Generation 2.3% 2.0% 0.2% 3.4% 7.9% Losses due to uncontrollable 2 factors (5)-(1) 5.6% (ii) On the basis of Maximum possible plant generation

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additional generation loss to UJVN Limited) is on account of (i) Equipment break down (ii) Flushing and Choking (iii) System Condition (iv) Flood passing and other reasons. UJVN Limited computes on a daily basis, the generation opportunity missed by it on account of these reasons. Thus the maximum that Chilla Power Station possibly could have generated (with 100% Unit availability and with no generation loss on account of any reason) is the gross generation by its Units and the generation loss suffered by it. This is an equally good approach for an existing plant for computing Design Energy when compared with the method of computing Design Energy on the basis of river discharge data as it is based on existing unit efficiencies instead of their design values, considers the impact of other project design related issues and also operational restrictions imposed on the plant. The maximum possible year wise generation has been computed in table below:

Table 135: Year wise Maximum Possible Generation (MU) – Chilla Power Station Sr. no. Actual Gross Generation Maximum Year % Generation Loss (MU) Possible Dependabi (MU) Generation lity (MU) 1 910.02 35.20 945.22 2011-12 10.00 2 826.02 34.44 860.45 2007-08 20.00 3 775.16 66.20 841.35 2010-11 30.00 4 776.58 43.66 820.24 2008-09 40.00 5 688.90 123.11 812.01 2003-04 50.00 6 739.48 57.39 796.87 2009-10 60.00 7 746.07 34.91 780.98 2004-05 70.00 8 740.46 25.17 765.64 2006-07 80.00 9 607.40 154.01 761.41 2002-03 90.00 10 659.18 64.76 723.94 2005-06 100.00 On re-arranging the above data in the descending order and considering the 90% dependable year, the Design Energy for the Chilla Power Station is computed to be 718.98 MUs as given in table 136 below.

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Table 136: Design Energy – Chilla Power Station

Sr. No. Particular Unit Value 1 Dependable Year FY 2002-03 2 Maximum Possible Generation MUs 761.41 3 Plant Availability for FY 2002-03 % 56.71 4 Energy losses due to uncontrollable factors % 5.6% 5 Energy losses due to uncontrollable factors MUs 42.43 6 Design Energy (2)-(5) MUs 718.98

6.8.3 Determination of NAPAF

6.8.3.1 The actual average plant availability during the last 10 years is given in the table 137 below:

Table 137: Plant Availability during FY 2002- 12 – Chilla Power Station Sr. No (1) Month (2) Total Reserve Forced Planned Maintenance Total hours Plant Running Outage Outage Annual Capital (max) Availability Hrs. of all (Hrs.) (4) (Hrs.) (5) Mainten Major (Hrs.) (8) % (9) the units ance repairs (Hrs.) (Col. 3+Col. (Hrs.) (3) (Hrs.) (6) (7) 4)/Col.8 1 April 16904 2223 1210 8463 0 28800 66% 2 May 21091 1605 1205 5859 0 29760 76% 3 June 23244 1476 1029 3051 0 28800 86% 4 July 25973 1195 1725 867 0 29760 91% 5 August 26135 1622 1205 798 0 29760 93% 6 Sept 24879 1294 1288 1339 0 28800 91% 7 Oct 25670 1428 133 2433 0 29760 91% 8 Nov 19489 2325 1547 5535 0 28800 76% 9 Dec 17261 3817 287 8395 0 29760 71% 10 Jan 15731 4018 46 9965 0 29760 66% 11 Feb 14502 3523 397 8746 0 27168 66% 12 March 16476 2766 402 10116 0 29760 65% Total 247355 27292 10474 65567 0 350688 78%

6.8.3.2 The average plant availability during the last 10 years is around 78%. The Chilla Power Station experiences forced shut downs during the monsoon seasons. The reasons for these forced shut downs have been provided in the section below.

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6.8.4 Special Circumstances and Abnormal Operating Conditions

6.8.4.1 Since its commissioning, Chilla Power Station operates on base load during Monsoon but meets evening and morning peaks during lean discharge period as per the instructions of SLDC. But due to silting of reservoir upstream of Pashulok (Rishikesh) Barrage the peaking capacity has also reduced.

6.8.4.2 Study of the available inflow data revealed that the maximum capacity can be generated between May to September and partial between October to April. Lean discharge period is again utilised for planned annual or capital maintenance.

6.8.4.3 The silt which passes through the turbines is highly abrasive and contains substantial amount of quartzite angular particles which in turn causes severe damages to the underwater parts of the units, as a result of this the machines are losing efficiency at a rapid pace. Though efforts are on to combat this problem when first unit was opened for annual maintenance but no viable solution could be found. The problem of silt erosion is of such magnitude that for the first time in country runner chambers had to be replaced and special grouting of the same had to done.

6.8.4.4 Thus, it can be concluded that quite a good amount of energy is lost during monsoon season which is beyond the control of UJVN Limited. Annual loss of energy during monsoon due to flushing and choking over the period 2002-12 has been calculated in the table 134 and 138, which is around 2% of the gross generation and 25% of the total generation loss. Such annual loss should therefore be appropriately accounted for while computing Design Energy and plant availability.

6.8.5 Plant Outages and Breakdowns

6.8.5.1 Apart from above facts, when flood recedes lot of silt having substantial quartzite particles are lodged in cavities and caves on both banks of river which gets dislodged when level of river starts rising as a result of snow melting during

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summer season and is carried to the machines through water conductor system causing severe damage to under water parts and frequent plant outages which becomes beyond the control of UJVN Limited

6.8.5.2 The forced outage data for the period 2002-2012 has revealed that 29% of the total energy loss is on this account. The table below provides the details.

Table 138: % Generation Loss on account of various Factors – Chilla Power Station Sr. No. Month↓ B/D of Flushing & System Flood Total Equipment Choking Condition passing & (in MU) (in MU) (in MU) & Grid fail Any Other (in MU) Reasons (in MU) 1 April 5.54 1.06 0.54 4.50 11.63 2 May 13.49 5.24 1.73 20.60 41.06 3 June 7.79 5.55 0.90 97.33 111.57 4 July 44.66 53.26 2.02 34.35 134.30 5 August 45.31 60.42 3.79 37.68 147.19 6 September 56.65 26.59 2.69 51.40 137.32 7 October 4.52 8.05 0.82 17.64 31.03 8 November 1.64 0.00 0.58 1.36 3.58 9 December 2.79 0.00 0.34 1.38 4.51 10 January 0.80 0.00 0.80 0.00 1.60 11 Feburary 1.81 0.29 0.23 1.36 3.70 12 March 2.08 0.00 0.29 9.00 11.36 Total 187.06 160.46 14.73 276.59 638.84 % Generation Lost 29% 25% 2% 43% 100%

6.8.6 Auxiliary Consumption and Transformation Losses

6.8.6.1 The analysis of auxiliary consumption data of past 10 years reveals that the auxiliary consumption of Chilla Power Station is around 0.1% of the Gross Generation. Similarly the transformation losses of past 10 years for which the data is available has been analysed. These losses are 0.9% of the gross generation. Both auxiliary and transformation losses together constitute around 1.0 % of the Gross Generation.

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Table 139: Auxiliary and Transformation Losses – Chilla Power Station Sr. No Particulars Unit Value 1 Total Gross Generation (2002-12) MUs 7469.26 2 Total Aux. consumption (2002-12) MUs 9.05 3 Aux. consumption as a % of Gross Generation % 0.1% 4 Total Gross Generation (2002-12) MUs 7469.26 5 Total Transformation loss (2002-12) MUs 68.63 6 Transformation loss as a % of Gross Generation % 0.9% 7 Total Aux. and Transformation losses (2002-12) MUs 77.68 Total Aux. and Transformation losses as a % of 8 % 1.0% Gross Generation

6.8.6.2 UJVN Limited has taken steps to reduce the auxiliary consumption and transformation losses. Data of previous 4 years, which has already been submitted to Hon’ble UERC, as shown below, shows improvement in auxiliary and transformation losses.

Sr. No Year Transformation Auxiliary & line losses Consumption 1 FY 2010-11 0.19% 0.15% 2 FY 2009-10 0.02% 0.18% 3 FY 2008-09 0.41% 0.17% 4 FY 2007-08 0.16% 0.16% 5 Average 0.19% 0.17%

6.8.7 Inferences

6.8.7.1 Design Energy

The discharge data for Chilla Power Station is available on 10 daily (average) basis for the period April 2002 to March 2012. The Design Energy has been computed on the basis of data for each 10 daily average discharge of the 90% dependable year. Correspondingly the Design Energy is calculated (refer to the earlier Table 133) to be 778.95 MU after accounting for uncontrollable energy loss of 5.6%.

Design Energy was also calculated based on maximum possible generation (refer Table- 136) which comes to 718.98 MU.

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Chilla Power Station is quite old Power Station and has been under operation in silt laden water since its commissioning in the year 1980. This long operation period has resulted into excessive wear and tear of the hydro mechanical and electro mechanical equipment, thereby causing breakdown of machines. The condition of these equipment is deteriorating with passage of time. UJVN Ltd. is taking proactive action by taking up comprehensive RMU of the Project for revival and life extension of the project.

Keeping in view the long operational life of the project, it is proposed that Design Energy for Chilla Power Station may be considered as 718.98 MU which is the Design Energy computed using the second approach mentioned earlier. However, after completion of the proposed RMU works of the Project, UJVN Ltd. shall approach the Commission to revise the Design Energy of the Project.

6.8.7.2 NAPAF

UERC has prescribed principle for determination of Normative Plant Availability. Based on the principle given by UERC the annual plant availability has been calculated in the table 133 which comes to 76.37%.

Based on actual running hours, reserve hours, forced outage hours and plant outage hours for last 10 years plant average annual plant availability has been calculated to be 78% (refer table no 137) and this may be taken as NAPAF for Chilla Power Station for the control period.

6.8.7.3 Auxiliary Consumption and Transformation Loss

As explained in the earlier section, these losses are within the limit of 1% prescribed by UERC for Surface hydroelectric power generating stations with static excitation system.

6.8.8 Projections for the control period

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6.8.8.1 RMU works are proposed for the Chilla Power Station. The proposed RMU works are likely to result in (i) Extension of the Plant life by around 25 years (ii) Higher Plant Availability (iii) Increased operating efficiencies of plant. The RMU works for the entire plant is not likely to be completed during the control period. The unit wise schedule for implementing RMU is as given below:

Name of Date of Start Date of Unit Commissioning Unit-1 01.11.14 31.03.16 Unit-2 01.06.16 31.03.17 Unit-3 01.06.17 31.03.18 Unit-4 01.06.18 31.03.19

6.8.9 Impact of RMU works on Energy Generation

6.8.9.1 The proposed RMU of Chilla Power Station is likely to result in increased availability of plants and refurbishment of turbines and generators is likely to lead to increased efficiencies. On account of these measures the annual generation is likely to increase. Primary purpose of RMU is life extension of the project apart from increase in generation. After RMU, generation will increase from 684 MU (Pre-Tehri scenario) to 1074 MU (after commissioning of Tehri Hydroelectric Project). Capacity of machine will enhance from present 36 MW to 43.2 MW and install capacity of plant will increase from 144 MW to 172.8 MW on account of RMU.

6.8.10 Availability

6.8.10.1 The annual maintenance schedule and the RMU schedule proposed for Chilla Power Station under RMU works for the Control period is as given below:

2013-14

Unit No. Start Date End date Days Reasons 1 01-11-2013 15-12-2013 45 Annual Maintenance 2 11-12-2013 24-01-2014 45 Annual Maintenance 3 25-01-2014 10-03-2014 45 Annual Maintenance 4 06-03-2014 19-04-2014 45 Annual Maintenance

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2014-15

Unit No. Start Date End date Days Reasons 1 01-11-2014 31-03-2016 517 RMU 2 11-12-2014 24-01-2015 45 Annual Maintenance 3 25-01-2015 10-03-2015 45 Annual Maintenance 4 06-03-2015 19-04-2015 45 Annual Maintenance 2015-16

Unit No. Start Date End date Days Reasons 1 01-11-2014 31-03-2016 517 RMU 2 11-12-2015 24-01-2016 45 Annual Maintenance 3 25-01-2016 09-03-2016 45 Annual Maintenance 4 06-03-2016 19-04-2016 45 Annual Maintenance

6.8.10.2 After implementation of RMU works, full capacity of the plant is likely to be available for the entire year except during monsoon period and annual maintenance period. The plant availability during the control year considering maintenance schedule given above and forced outages expected (based on past data) during monsoon months is expected to be as given below:

Particulars Base Year FY 2013-14 FY 2014-15 FY 2015-16 Plant Availability (%) 78% 86.0% 77.4% 63.6%

6.8.10.3 The plant availability expected post RMU is likely to be around 88 %.

6.8.11 Auxiliary Consumption and Transformation losses

6.8.11.1 As stated above the auxiliary and transformation losses are within the limits prescribed by the Commission. During the control period these are expected to be within the limits prescribed by the Commission.

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6.9 TECHNICAL REPORT OF KHATIMA POWER STATION

6.9.1 Introduction

6.9.1.1 Khatima Power Station, with an Installed Capacity of 41.4 MW (3X13.8 MW) is situated at Lohiahead (Khatima), District Udham Singh Nagar of Uttarakhand. Khatima hydro power Station is an irrigation canal based project. The project is located at a distance of about 6 km from Khatima town and connected by road. Meter Gauge rail connection is also available up to Khatima town.

6.9.1.2 The Sharda Canal / Power Channel draws water from river Sharda through Banbasa Barrage located at a distance of about 16 km upstream of the Power Station at Banbasa near Tanakpur. The Power Station units were commissioned in 1955 & 1956. Three English Electric make generating units of 13.8 MW capacity each have been installed, totalling to aggregate capacity of 41.4 MW. The Power Station has been operating since more than 55 years & maximum capacity of 41.4 MW has been achieved in the past.

6.9.1.3 Power generated from Kaplan turbines at 11 kV is stepped up to 132 kV via three phase 17.5 MVA transformers. The generated power is evacuated through 2 nos. 132 kV feeders to 132 kV Dohna substation (Bareilly) and 3 nos. 33 kV feeders (one through 40 MVA, 132/33 kV transformer and other 2 nos. feeders through 20 MVA, 132 / 33 kV transformer) to Diesel PH, industrial supply and Tanakpur Project of NHPC respectively.

6.9.1.4 Due to long operation of about 55 years, the operating efficiency of the machines has gone down considerably. Generating units have derated and the condition of their auxiliaries, instruments, protective relays & control equipment have deteriorated to such an extent that the combined output of the Power Station is restricted to about 25-28 MW against the rated capacity of 41.4 MW.

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6.9.1.5 The Power Station is located on the downstream of the Banbasa Barrage over river Sharda at a distance of 1.6 km on the irrigation canal which takes off from the Barrage. The Power Station was commissioned in the year 1956.

6.9.1.6 The surface Power Station comprising 3 units of 13.8 MW each with vertical Kaplan turbines of 19200 BHP output coupled with synchronous generator of 17.25 MW rated output, 0.8 lagging power factor is located on the unlined irrigation canal. The water of canal is utilized for the irrigation purpose in the command area of the canal.

6.9.1.7 The Power Station has a design head of 17.98 m. The Khatima Power Station is a low head plant with a design discharge of 269 cum.

6.9.1.8 The discharge in the canal is regulated by UP Irrigation Department depending upon the irrigation requirement in the command area of the Irrigation canal and is also limited to the capacity of the escape channel downstream of the Power Station in case there is no demand.

6.9.1.9 Due to operations of machines for past so many years, efficiency of machines has substantially decreased and availability of machines has been adversely affected, in spite of best and timely maintenance.

6.9.2 Determination of Design Energy

6.9.2.1 Khatima Power Station is a run of the river type plant. For computing the Design Energy two methodologies have been considered i.e. (i) on the basis of average of 10 daily discharges for calculation of NAPAF for Run-of-river type plant as per provision of UERC MYT 2011 Regulations “To be determined plant-wise, based on 10-day Design Energy data, moderated by past experience where available /relevant ”and (ii) the maximum generation possible from the Khatima Power Station considering that there were no machine and other outages. Due to non- availability of 90% dependable 10 daily inflows pattern as approved in the DPR of

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the project, Design Energy and NAPAF have been calculated on the basis of available past reliable 10 daily discharge data.

(i) On the basis of Average of 10 daily discharges

Reliable 10 daily (average) discharge data for Khatima Power Station is available for the period April 2001 to March 2012 and the same has been considered for determination of 90% dependable year and Design Energy This data is provided in the annexure no. 8. On considering the yearly average daily discharge data for the same period, the 90% dependable year is found to be 2009-10, as given in table below:

Table 140: 90% dependable year – Khatima Power Station Sr. No. 10 Daily Year % Average Dependability Discharge 1 219.30 04-05 9.09 2 215.31 02-03 18.18 3 211.66 05-06 27.27 4 209.89 07-08 36.36 5 208.17 01-02 45.45 6 206.70 06-07 54.55 7 202.94 10-11 63.64 8 199.35 03-04 72.73 9 194.12 08-09 81.82 10 193.98 09-10 90.91 11 153.61 11-12 100.00 For computation of possible energy generation corresponding to the discharge considered, generator and turbine efficiencies have been considered as 0.96 and 0.90 as per the past design records available with UJVN Limited. Design Energy estimation is sensitive to these assumptions. The plant has been in operation for last 55 years and it is quite possible that these parameters may have deteriorated from their design values. In the absence of detailed technical study on the present efficiency levels of generator and turbine of Khatima Power Station, UJVN Limited for the present exercise is constrained to use these efficiency levels for

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computational purpose though the actual efficiency levels are expected to be lower.

The energy generation corresponding to the 10 daily discharges for 2009-10 with 95% of the Installed capacity is given in the table below:

Table 141: Discharge & Generation Data – Khatima Power Station Sr.no. Month Net Discharge Net Head Power Potential Energy (kWh) (cumecs) (meter) (kW) 1 April-I 103.3 18.0 15,739.0 37,77,357.6 2 April-II 116.9 18.0 17,817.3 42,76,144.5 3 April-III 126.8 18.0 19,330.7 46,39,359.9 4 May-I 166.7 18.0 25,397.6 60,95,432.3 5 May-II 144.2 18.0 21,976.4 52,74,339.6 6 May-III 220.7 18.0 33,635.1 88,79,669.7 7 June-I 235.2 18.0 35,845.1 86,02,830.5 8 June-II 168.2 18.0 25,628.9 61,50,945.1 9 June-III 269.6 18.0 41,086.1 94,39,200.0 10 July-I 276.8 18.0 42,183.5 94,39,200.0 11 July-II 318.5 18.0 48,542.2 94,39,200.0 12 July-III 318.6 18.0 48,555.3 1,03,83,120.0 13 Aug-I 291.5 18.0 44,423.6 94,39,200.0 14 Aug-II 282.6 18.0 43,068.2 94,39,200.0 15 Aug-III 301.7 18.0 45,974.7 1,03,83,120.0 16 Sept-I 304.6 18.0 46,426.8 94,39,200.0 17 Sept-III 302.0 18.0 46,021.6 94,39,200.0 18 Sept-III 298.0 18.0 45,410.6 94,39,200.0 19 Oct-I 210.4 18.0 32,061.4 76,94,740.2 20 Oct-II 115.1 18.0 17,542.4 42,10,171.2 21 Oct-III 117.3 18.0 17,875.4 47,19,107.8 22 Nov-I 132.5 18.0 20,198.9 48,47,740.2 23 Nov-II 129.4 18.0 19,718.6 47,32,468.2 24 Nov-III 152.8 18.0 23,290.0 55,89,602.8 25 Dec-I 181.6 18.0 27,670.5 66,40,928.6 26 Dec-II 197.8 18.0 30,144.5 72,34,688.0 27 Dec-III 177.6 18.0 27,065.2 71,45,204.6 28 Jan-I 172.1 18.0 26,221.9 62,93,248.5 29 Jan-II 158.4 18.0 24,136.3 57,92,701.0 30 Jan-III 137.3 18.0 20,919.3 55,22,697.4 31 Feb-I 135.7 18.0 20,674.0 49,61,769.3 32 Feb-II 158.4 18.0 24,136.7 57,92,804.6 33 Feb-III 141.5 18.0 21,558.5 41,39,226.7 34 March-I 148.4 18.0 22,619.4 54,28,657.0 35 March-II 131.3 18.0 20,003.0 48,00,720.0 36 March-III 140.0 18.0 21,332.8 56,31,858.8 Annual Energy Generation 24,51,54,254.1

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Table 142: Design Energy- Khatima Power Station Sr. No Particulars Unit Value 1 Generation Loss due to uncontrollable situation % 4.7% 2 Energy loss during monsoon and forced outages kWh 11464688.3 3 Design Energy kWh 233689565.8 4 Design Energy (MU) MUs 233.7 5 Plant Availability of FY 09-10 % 84.8 While determining Design Energy, a 4.7% (based on losses experienced during the operation of the plant) reduction in the energy generation has been considered. This reduction has been considered to take into account generation loss due to uncontrollable factors such as forced stoppages of machines and outages to prevent damage to the machines due to heavy silting during flash floods, flood passing and grid failure etc. These losses represent hydrological risk and other controllable risks which UJVN Limited cannot control in spite of its robust operating procedures. The figure of 4.7 % has been determined considering generation loss on account of uncontrollable factors as a percentage of maximum possible generation without any unit and other outages on the basis of past data of the period 2000-12. The details of these losses are provided in the table below:

Table 143: Uncontrollable Losses – Khatima Power Station Sr. No % losses B/D of Flushing & System Flood Total (5) Equipment Choking Condition Passing & (1) (2) (3) Any Other Reason (4) Gross losses as % of Max. 1 Gross Generation 2.4% 3.5% 1.2% 0.0% 7.1% Losses due to uncontrollable 2 factors (5)-(1) 4.7% (ii) On the basis of Maximum possible plant generation

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additional generation loss to UJVN Limited) is on account of (i) Equipment break down (ii) Flushing and Choking (iii) System Condition (iv) Flood passing and other reasons. UJVNL computes on a daily basis, the generation opportunity missed by it on account of these reasons. Thus the maximum that Khatima Power Station possibly could have generated (with 100% Unit availability and with no generation loss on account of any reason) is the gross generation by its Units and the generation loss suffered by it. This is an equally good approach for an existing plant for computing Design Energy when compared with the method of computing Design Energy on the basis of river discharge data as it is based on existing unit efficiencies instead of their design values, considers the impact of other project design related issues and also operational restrictions imposed on the plant. The maximum possible year wise generation has been computed in table below:

Table 144: Year wise Maximum Possible Generation (MU) – Khatima Power Station Sr. no. Actual Gross Generation Maximum Year % Generation Loss (MU) Possible Dependabi (MU) Generation lity (MU) 1 165.01 26.17 191.18 2005-06 8.33 2 183.42 7.74 191.16 2004-05 16.67 3 163.07 20.87 183.94 2002-03 25.00 4 171.53 9.94 181.48 2001-02 33.33 5 165.49 12.99 178.48 2000-01 41.67 6 154.04 18.75 172.79 2006-07 50.00 7 157.24 14.48 171.72 2003-04 58.33 8 164.00 3.68 167.68 2011-12 66.67 9 155.43 10.18 165.60 2007-08 75.00 10 155.94 6.16 162.10 2010-11 83.33 11 151.01 9.05 160.06 2009-10 91.67 12 140.88 6.64 147.52 2008-09 100.00 On re-arranging the above data in the descending order and considering the 90% dependable year, the Design Energy for the Khatima Power Station after accounting for losses on account of uncontrollable factors is computed to be 152.57 MUs as given in table below;

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Table 145: Design Energy – Khatima Power Station Sr. No. Particular Unit Value 1 Dependable Year FY 2009-10 2 Maximum Possible Generation MUs 160.06 3 Plant Availability for FY 2009-10 % 84.82 4 Energy losses due to uncontrollable factors % 4.7% 5 Energy losses due to uncontrollable factors MUs 7.49 6 Design Energy (2)-(5) MUs 152.57 6.9.3 Determination of NAPAF

6.9.3.1 Actual average plant availability during the last 12 years is given in the table below:

Table 146: Plant Availability during FY 2000 - 12 – Khatima Power Station Sr. No (1) Month (2) Total Reserve Forced Planned Maintenance Total hours Plant Running Outage Outage Annual Capital (max) Availability Hrs. of all (Hrs.) (4) (Hrs.) (5) Mainten Major (Hrs.) (8) % (9) the units ance repairs (Hrs.) (Col. 3+Col. (Hrs.) (3) (Hrs.) (6) (7) 4)/Col.8 1 April 14810 2777 1431 6902 0 25920 68% 2 May 17705 2634 3247 3198 0 26784 76% 3 June 19192 1706 3132 1890 0 25920 81% 4 July 22471 1248 2564 501 0 26784 89% 5 August 23437 1274 1766 307 0 26784 92% 6 Sept 22841 1470 1341 268 0 25920 94% 7 Oct 21129 4465 829 361 0 26784 96% 8 Nov 15813 4109 1090 4908 0 25920 77% 9 Dec 16216 2789 111 7668 0 26784 71% 10 Jan 14568 3419 526 8271 0 26784 67% 11 Feb 11975 3579 1102 7752 0 24408 64% 12 March 13327 4695 1222 7540 0 26784 67% Total 213484 34165 18361 49566 0 315576 78%

6.9.3.2 The average plant availability for the period 2000-12 is around 78%.The Khatima plant experiences forced shut downs during the monsoon seasons. The reasons for these forced shut downs have been provided in the section below.

6.9.4

6.9.5 Special Circumstances and Abnormal Operating Conditions

6.9.5.1 Since its commissioning, Khatima Power Station operates on base load during monsoon and non-monsoon periods. Study of the available inflow data revealed that the maximum capacity can be generated between May to September and

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partially between October to April. Lean discharge period is again utilised for planned annual or capital maintenance.

6.9.5.2 Annual loss of energy during Monsoon due to flushing and choking over the period 2000-12 has been calculated in the tables 143 and 147, which is around 3.5% of the gross generation and 49% of the total generation loss. Such annual loss should therefore be appropriately accounted for while computing Design Energy and plant availability.

6.9.6 Plant Outages and Breakdowns

6.9.6.1 The forced outage data for the period 2000-2012 has revealed that 34% of the total energy loss is on this account. The table below provides the details.

Table 147: % Generation Loss on account of various Factors – Khatima Power Station

Sr. No. Month↓ B/D of Flushing & System Flood Total Equipment Choking Condition passing & (in MU) (in MU) (in MU) & Grid fail Any Other (in MU) Reasons (in MU) 1 April 4.03 2.30 1.27 0.00 7.59 2 May 6.07 3.01 3.89 0.00 12.97 3 June 8.29 6.61 7.14 0.00 22.04 4 July 14.78 13.63 3.33 0.00 31.73 5 August 6.88 14.91 3.12 0.00 24.92 6 September 4.53 16.47 1.36 0.00 22.36 7 October 1.54 8.19 0.90 0.00 10.64 8 November 1.45 2.75 0.69 0.00 4.89 9 December 0.23 1.09 0.68 0.00 2.00 10 January 0.01 1.02 1.26 0.00 2.29 11 Feburary 0.01 0.84 1.19 0.00 2.04 12 March 1.85 0.76 0.58 0.00 3.19 Total 49.67 71.57 25.41 0.00 146.64 Generation Lost 34% 49% 17% 0% 100%

6.9.7

6.9.8 Auxiliary Consumption and Transformation Losses

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6.9.8.1 The analysis of auxiliary consumption data of past 12 years reveals that the auxiliary consumption of Khatima Power Station is around 0.3% of the Gross Generation. Similarly the transformation losses of past 12 years for which the data is available has been analysed. The transformation losses are 0.5% of the gross generation. Both auxiliary and transformation losses together constitute around 0.8 % of the Gross Generation.

Table 148: Auxiliary and Transformation Losses – Khatima Power Station Sr. No. Particulars Unit Value 1 Total Gross Generation (2000-12) MUs 1927.06 2 Total Aux. consumption (2000-12) MUs 5.71 3 Aux. consumption as a % of Gross Generation % 0.3% 4 Total Gross Generation (2000-12) MUs 1927.06 5 Total Transformation loss (2000-12) MUs 9.64 6 Transformation loss as a % of Gross Generation % 0.5% 7 Total Aux. and Transformation losses (2000-12) MUs 15.34 Total Aux. and Transformation losses as a % of 8 % 0.8% Gross Generation

6.9.9 Inferences

6.9.9.1 Design Energy

The discharge data for Khatima Power Station is available on 10 daily (average) basis for the period April 2001 to March 2012. The data for each 10 daily average discharge of the year is selected for 90% dependable year. Correspondingly the Design Energy is calculated (refer the earlier table 142) to be 233.7 MU after accounting for uncontrollable energy loss of 4.7%.

Design Energy has also been calculated based on maximum possible generation (refer to the earlier Table 145) which comes to 152.57 MU.

Khatima Power Station is quite old Power Station and has been under operation since its commissioning in the year 1955. This long operation period has resulted

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Keeping in view the long operational life of the project, it is proposed that Design Energy for Khatima Power Station may be considered as 152.57 MU which is the Design Energy computed using the second approach mentioned earlier. However, after completion of the proposed RMU works of the Project, UJVN Ltd. shall approach the Commission to revise the Design Energy of the Project.

6.9.9.2 NAPAF

UERC has prescribed principle for its determination of NAPAF. Based on the principle given by UERC, the annual plant availability has been calculated in the earlier table 142, which comes to 84.82%.

Based on actual running hours, reserve hours, forced outage hours and plant outage hours for last 12 years average annual plant availability has been calculated in the earlier table 146 which comes to only 78% and this may be taken as NAPAF for Khatima Power Station for control period.

6.9.9.3 Auxiliary Consumption and Transformation Loss

As explained in the earlier section these losses exceed the limit of 0.7% by 0.1% prescribed by UERC for Surface hydroelectric power generating stations with rotary excitation system. UJVN Limited proposes to take remedial measures during the proposed RMU to reduce these losses within the prescribed limits prescribed by the Commission.

6.9.10 Projection for the control period

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6.9.10.1 RMU works are proposed for the Khatima Power Station. The proposed RMU works are likely to result in (i) Extension of the Plant life by around 25 years (ii) Higher Plant Availability (iii) Increased operating efficiencies of plant. The RMU works for the plant is likely to be completed during the control period. The unit wise schedule for implementing RMU is as given below:

Name of Date of Start Date of Unit Commissioning Unit-1 01.10.12 31.03.14 Unit-2 01.04.14 31.01.15 Unit-3 01.01.15 31.10.15

6.9.11 Impact of RMU works on Energy generation

6.9.11.1 The proposed RMU of Khatima Power Station is likely to result in increased plant availability and refurbishment of turbines and generators is likely to result in increased efficiencies. These measures could yield energy gains of the order of 57.7% if the same level of water discharge is considered pre and post RMU. Primary purpose of RMU is life extension of the project apart from increase in generation. After RMU, generation will increase from 149.03 MU to 235 MU (as per DPR) subject to same water discharge.

6.9.12 Availability

6.9.12.1 The annual maintenance schedule and the maintenance schedule proposed for Khatima Power Station under RMU works for the Control period is as given below:

FY2013-14

Unit No. Start Date End date Days Reasons 1 01-10-2012 31-03-2014 547 RMU Interim Maintenance, as 2 15-12-2013 31-12-2013 17 Unit is to be taken under RMU soon 3 10-01-2014 23-02-2014 45 Annual Maintenance FY2014-15

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Unit No. Start Date End date Days Reasons 1 15-11-2014 29-12-2014 45 Annual Maintenance 2 01-04-2014 31-01-2015 306 RMU 3 01-01-2015 31-10-2015 304 RMU FY2015-16

Unit No. Start Date End date Days Reasons 1 12-11-2015 26-12-2015 45 Annual Maintenance 2 01-01-2016 14-02-2016 45 Annual Maintenance General inspection, interim repairs may be 3 15-02-2016 05-03-2016 20 carried out as the RMU work of the unit has just completed

6.9.12.2 The plant availability during the control year considering maintenance schedule given above and forced outages expected (based on past data) during monsoon months is expected to be as given below:

Particulars Base Year FY 2013-14 FY 2014-15 FY 2015-16 Plant Availability (%) 72% 58.0% 56.4% 65.5%

6.9.12.3 The plant availability expected post RMU is likely to be around 80 %.

6.9.13 Auxiliary Consumption and Transformation losses

6.9.13.1 As explained in the earlier section these losses exceed the limit of 0.7% by 0.1% prescribed by UERC for Surface hydroelectric power generating stations with rotary excitation system. Khatima Power Station is expected to achieve normative auxiliary consumption and transformation loss level after completion of the RMU works.

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6.10 TECHNICAL REPORT OF RAMGANGA POWER STATION

6.10.1 Introduction:

6.10.1.1 Ramganga Power Station has an Installed capacity of 198 MW (3X66 MW). Ramganga Power Station is a Reservoir based scheme on river Ramganga located near the famous Jim Corbett Park in district Pauri Garwhal. It utilizes water stored for irrigation purpose. The water release from Ramganga Dam is regulated by the UP Irrigation Department. The generation is dependent on the rain in the catchment area and on the drawl of water for irrigation purpose in the command area of the canal in the state of Uttar Pradesh.

6.10.1.2 The surface Power Station is located at the toe of the dam and houses 3 units of 66 MW each with vertical Francis turbines of 92400 HP. The Ramganga Power Station is a medium head scheme with a design head of 84.4 m and a design discharge of 285 cum.

6.10.1.3 The project has unique challenges in operation due to restriction imposed on the release of water in the water conductor system by the UP irrigation Department which is dependent on the demand of water in the command area of the canal in Uttar Pradesh based on the irrigation requirement.

6.10.2 Water Availability

6.10.2.1 Ramganga Power Station utilizes discharge from Ramganga reservoir for power generation. Since this is an irrigation based Power Station, the water released from the reservoir is as per irrigation requirement in the downstream areas of Uttar Pradesh. Water discharge utilized for power generation is measured by irrigation authorities.

6.10.2.2 The water availability from the reservoir for generation during different periods of the year is as follows:-

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6.10.2.3 Summer

During summer water discharge from the reservoir can cater to two units operating at full capacity or three units operating at part capacity.

6.10.2.4 Winter

During winter, due to greater demand of water for irrigation purposes in western part of U.P, the water discharge from the reservoir is highest and generally all the three units operate at about 85-90% of full capacity.

6.10.2.5 Rainy Season

During rainy season water is stored in the dam. Generally, this period falls between 16th June to 15th October of each year and to utilize this period effectively annual maintenance of Ramganga Power Station is planned. However, if during this period the reservoir level reaches 365.3 m, the maintenance of the machines are deferred and the machines are kept in ready condition to avoid any wastage of water.

6.10.2.6 The maximum average discharge recorded in the reservoir is 42049 cusecs in ten days block from 21-31 December and minimum average discharge of 102 cusecs in ten days block from 1-10 September.

6.10.3 Head Availability

6.10.3.1 Head Race Level

At the upstream of Power Station there is a spillway (on the right bank) for by- passing the surplus water to tail race. Water is released to the spillway from headrace through a radial gate system, but this system is rarely used for spilling of water as generally all the water is discharged through the machines. Normally, the head race level varies from maximum to minimum during October to June. It is highest in October and lowest in June.

6.10.3.2 Tail Race Level

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6.10.3.3 Tail race level varies according to the generation from the Project. It is minimum in the month of October and maximum in the month of June.

The theoretical (as per original DPR prepared during construction) normal, maximum and minimum tail race levels are as follows:-

. Normal Tail water level : 258.700 m

. Maximum Tail water level : 278.000 m

. Minimum Tail water level : 256.100 m

6.10.4 Effect of discharge through spill way by-pass / irrigation tunnel T-2 on tail race level

6.10.4.1 The spill way by-pass / irrigation tunnel T-2 joins tail race approximately 70 m parallel to the Power Station. The effect of backwater on tail race level has been negligible on variation of head unless heavy flood occurs and irrigation department is compelled to open the spill way radial gates. The discharge through tunnel T-2 is in the range of 150-200 cusec day during lean season. It is not possible to run the machines on such low discharge as turbines cannot be run below 60-70 % of rated load otherwise there will be enormous hunting and under water parts will get severely damaged.

6.10.5 Operating Head Range and Design Head

6.10.5.1 Maximum and Minimum head of Ramganga Power Station is as follows:-

a. Operating Head Range

Maximum Head

Maximum Head Water Level 366.200 m

Minimum Tail Water Level 256.100 m

Maximum Head (Theoretical) 110.100 m

Minimum Net Head

Minimum Head Water Level 332.900 m

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Maximum Tail Water Level 278.000 m

Minimum Head (Theoretical) 54.900 m

b. Design Net Head

Ramganga Power Station being a reservoir scheme, the head (water level) is not constant but varies from maximum to minimum from 16th October to 15th June (generating season) and from 16th June to 15th October (water storage period). The tailrace water level increases with increase in generating factor and at maximum discharge, the available head is minimum. The design net head of Ramganga Power Station is 84.4 m. The maximum to minimum net head of the Power Station varies from 108.85 m to 54.9 m.

This Power Station was commissioned in the year 1975. Due to operations of machines for past 37 years, efficiency of machines has substantially decreased and availability of machines has been adversely affected in spite of robust operational and maintenance schedule.

6.10.6 Determination of Design Energy

6.10.6.1 The Design Energy is proposed to be computed on the basis of average of 10 daily discharges as prescribed by UERC in its regulations.

6.10.6.2 Average of 10 daily discharges

The discharge data for Ramganga River is available on yearly (average) basis for the period 1992-93 to 2011-12 as given in the table 149 below. This discharge data has been considered for determining 90% dependable year.

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Table 149: Annual Discharge

Sr. No Year Full Minimum Discharge available Reservoir Draw Down for Generation in M. Level(FRL) Level Cum (MDDL) 1 1992-93 353.27 329.09 1,315.08 2 1993-94 362.30 329.00 2,017.33 3 1994-95 356.07 324.87 1,806.49 4 1995-96 358.58 317.16 1,677.65 5 1996-97 351.60 328.21 1,628.57 6 1997-98 341.51 304.55 647.51 7 1998-99 365.30 325.11 2,128.71 8 1999-00 356.00 331.94 1,526.27 9 2000-01 365.40 332.51 2,202.81 10 2001-02 351.48 334.92 1,316.85 11 2002-03 341.20 325.73 927.14 12 2003-04 351.51 323.04 1,397.43 13 2004-05 349.82 312.06 1,370.29 14 2005-06 357.51 317.17 1,650.87 15 2006-07 342.85 322.25 897.87 16 2007-08 359.73 327.01 1,334.03 17 2008-09 356.41 328.44 1,335.96 18 2009-10 338.47 320.26 1,061.23 19 2010-11 365.40 319.20 1,102.31 20 2011-12 362.55 340.00 1,883.23

6.10.6.3 On stacking the discharge data in the descending order, the dependable year is determined to be 2002-03 as given in the table 150 below.

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Table 150: 90% Dependable year

Sr. No. 10 Daily Year % Average Dependability Discharge 1 2,202.81 2000-01 5 2 2,128.71 1998-99 10 3 2,017.33 1993-94 15 4 1,883.23 2011-12 20 5 1,806.49 1994-95 25 6 1,677.65 1995-96 30 7 1,650.87 2005-06 35 8 1,628.57 1996-97 40 9 1,526.27 1999-00 45 10 1,397.43 2003-04 50 11 1,370.29 2004-05 55 12 1,335.96 2008-09 60 13 1,334.03 2007-08 65 14 1,316.85 2001-02 70 15 1,315.08 1992-93 75 16 1,102.31 2010-11 80 17 1,061.23 2009-10 85 18 927.14 2002-03 90 19 897.87 2006-07 95 20 647.51 1997-98 100

6.10.6.4 From the above table the 90 % dependable year is determined to be FY 2002-03. For computation of Design Energy corresponding to the discharge considered, generator and turbine efficiencies have been considered as 0.97 and 0.92 as per the design records available with UJVN Limited. Design Energy estimation is sensitive to these assumptions and in the absence of detailed technical study on the present efficiency levels of generator and turbine of Ramganga Power Station, UJVN Limited is constrained to use these efficiency levels though actual levels are expected to be lower.

6.10.6.5 The 10 daily discharge data of dependable year 2002-03 was then utilized to calculate corresponding energy generation which is given in the table 151 below:

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Table 151: Energy Generation potential for the dependable year on 10 daily discharge basis

Sr.no. Month Net Discharge Net Head Power Potential Energy (kWh) (cumecs) (meter) (kW) 1 April-I 69.00 84.40 54.27 13.03 2 April-II 61.00 84.40 47.98 11.52 3 April-III 102.00 84.40 80.23 19.26 4 May-I 112.00 84.40 88.10 21.14 5 May-II 46.00 84.40 36.18 8.68 6 May-III 27.00 84.40 21.24 5.10 7 June-I 32.00 84.40 25.17 6.04 8 June-II 70.00 84.40 55.06 13.21 9 June-III 92.00 84.40 72.36 17.37 10 July-I - 84.40 - - 11 July-II - 84.40 - - 12 July-III - 84.40 - - 13 Aug-I - 84.40 - - 14 Aug-II - 84.40 - - 15 Aug-III - 84.40 - - 16 Sept-I - 84.40 - - 17 Sept-III - 84.40 - - 18 Sept-III - 84.40 - - 19 Oct-I - 84.40 - - 20 Oct-II - 84.40 - - 21 Oct-III - 84.40 - - 22 Nov-I 3.00 84.40 2.36 0.57 23 Nov-II - 84.40 - - 24 Nov-III 10.00 84.40 7.87 1.89 25 Dec-I 18.00 84.40 14.16 3.40 26 Dec-II 49.00 84.40 38.54 9.25 27 Dec-III 55.00 84.40 43.26 10.38 28 Jan-I 21.00 84.40 16.52 3.96 29 Jan-II 73.00 84.40 57.42 13.78 30 Jan-III 108.00 84.40 84.95 20.39 31 Feb-I 46.00 84.40 36.18 8.68 32 Feb-II 55.00 84.40 43.26 10.38 33 Feb-III 80.00 84.40 62.93 15.10 34 March-I 65.00 84.40 51.13 12.27 35 March-II 94.00 84.40 73.94 17.74 36 March-III 72.00 84.40 56.63 13.59 Annual Energy Generation 256.7

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6.10.6.6 On the basis of 10 daily discharge data of 90 % dependable year, the Design Energy is computed to be 256.7 MU. No generation loss has been considered as there is no spilling of water.

6.10.6.7 For run off the river plants an alternate approach of computing Design Energy on the basis of maximum possible generation was also considered. This approach is not being considered for the Ramganga Power Station as generation from the plant is regulated on the basis of the irrigation requirements and is not entirely governed by the plant availability. Thus this method could lead to erroneous conclusions.

6.10.7 Determination of NAPAF

6.10.7.1 Ramganga Power Station can be classified as Storage and Pondage type Power Station. However this Power Station is run strictly in accordance with the requirement of UP Irrigation Department as mentioned earlier. UERC has not prescribed principles for irrigation need based Power Station though it has prescribed principles for Storage and Pondage type power station. The Commission is requested to prescribe principles for determination of NAPAF for such Power Stations. Though, as discussed the principles prescribed by UERC for determination of NAPAF for storage and pondage type of Power Stations are not applicable to Ramganga Power Station per se but UJVN Ltd. has used these principles (in the absence of the principle for such plants) to determine NAPAF for the Power Station and to show the impact of control of UP Irrigation department on plant operations.

6.10.7.2 UERC in its Regulations UERC (Terms and conditions for determination of tariff) Regulations 2011 has prescribed either NAPAF or the principle for determination for NAPAF for Storage and Pondage type plants depending upon difference between Full Reservoir Level (FRL) and Minimum Draw Down Level (MDDL). According to these regulations for Storage and Pondage type plants with head variation between Full Reservoir Level (FRL) and Minimum Draw Down Level (MDDL) of:

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up to 8% and where plant availability is not affected by silt: NAPAF is 90%, but if the plant is significantly affected by the slit a margin of 5% is provided. The NAPAF for such plants if 85%.

more than 8% and where plant availability is not affected by silt, the month wise peaking capability as provided by the project authorities in the DPR (approved by CEA or the State Govt.), shall form basis of fixation of NAPAF.

6.10.7.3 Ramganga Power Station belongs to the latter category of Power Stations as variation between net head recordings in October and June 16th is more than 8%. However the principle prescribed by UERC for such Power Stations cannot be applied as such to (leaving aside the limitations expressed earlier). Ramganga Power Station is 37 years old and the original DPR of the Power Station is not available with UJVN Ltd. In the absence of the DPR it is proposed to compute month wise peaking capability on the basis of actual running data available with UJVN Ltd. and determine NAPAF accordingly.

6.10.8 Peaking Capability

6.10.8.1 Daily peaking data for the period April 2002 to March 2012 which is available with UJVN Limited was analysed as per the principles prescribed and illustration provided in the Regulations by UERC. The analysis reveals that NAPAF on yearly basis is only 19% and 38% for the period 1st December to 31st March when plant is operational to meet irrigation requirements. In the latter method of calculation of NAPAF, the fact that operations of the plant are governed by irrigation requirements and plant is not in operation for around 8 months has been considered. Even during the period December to March when the plant is in operation most of the time permissible water discharge is not sufficient to run the plant at (or near) its rated capacity. The analysis is provided in the table-152 below:

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Table 152: Plant availability based on Peaking Capability

Sr. no. Month Average three Considering hour Peaking months of Dec, Jan Capacity , Feb & March only 1 April 49 - 2 May 45 - 3 June 29 - 4 July 1 - 5 August 5 - 6 September 4 - 7 October 5 - 8 November 21 - 9 December 60 60 10 January 85 85 11 February 85 85 12 March 80 80 Weighted average of 39 77 13 peaking capability 14 Forced Outage 2% 1.5% Expected Average 38 76 15 peaking Capability 16 Installed Capacity 198 17 NAPAF 19% 38%

6.10.8.2 Plant availability as calculated in any way is not a reflection of the operational efficiencies of the plant because the prescribed methodology does not capture the scenario when plant is available for generation but cannot be scheduled because water discharges are not within the control of UJVN Limited. The actual average plant availability computed on the basis of availability of units for generation (though not scheduled) during last five years (2007-12) has been 84.65% as given in the table-153 below. There has been no generation loss on account of non- availability of units as regular and other maintenance requirements are scheduled during season (monsoon) when plant is not in operation.

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Table 153: Plant Availability during 2007-12

Sr. no. Year Availability (%) 1 2007-08 75.66 2 2008-09 80.24 3 2009-10 85.12 4 2010-11 92.98 5 2011-12 89.26 6 Average 84.65

6.10.8.3 Ramganga Power Station is neither a run of the river nor a storage Power Station solely dedicated for electricity generation. Hon’ble UERC is requested to make appropriate amendments in its existing tariff regulations to accommodate Ramganga Power Station.

6.10.9 Plant Outages and Break Downs

6.10.9.1 Annual/ capital maintenance of the plant is scheduled during the period 16th June to 15th October. During this period, water is stored in the dam and is released later as per the irrigation requirement. Unplanned outages even if they occur when Power Station is generating (December- March) generally do not result in generation loss as there is no spillage of water and the water is retained in the reservoir for future generation. The exception to this could be if the reservoir reaches the level of 365.300 m before 15th of October and machines are still under maintenance. However such situations are rare.

6.10.10 Auxiliary Consumption and Transformation Losses

6.10.10.1 The analysis of auxiliary consumption data for the period 2002-12 reveals that the auxiliary consumption of Ramganga Power Station is around 0.47% of the Gross Generation.

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Table 154: Auxiliary and Transformation losses

Sr. no. Year Gross Auxiliary Generation Consumption (MU) (MU) 1 2002-03 183.71 0.76 2 2003-04 209.16 0.94 3 2004-05 211.88 2.36 4 2005-06 333.29 1.27 5 2006-07 154.17 1.10 6 2007-08 279.06 1.17 7 2008-09 325.48 1.34 8 2009-10 174.29 1.20 9 2010-11 325.62 1.07 10 2011-12 416.42 1.07 11 Total 2,613.07 12.28

6.10.10.2 Auxiliary consumption as percentage of gross generation for past 10 years is 0.46%. The transformation loss for the period 2007-11 for which data is available (it has been shared with the Commission) have been analysed and has been found to be 1.16% of the gross generation for the period. Thus both auxiliary and transformation losses together constitute around 1.6% of the Gross Generation.

6.10.11 Inferences:

6.10.11.1 Design Energy

Ramganga Power Station is quite old Power Station and has been under operation since its commissioning in the year 1975. This long operation period has resulted into excessive wear and tear of the hydro mechanical and electro mechanical equipments, thereby causing breakdown of machines. The condition of these equipments are deteriorating with passage of time. UJVN Ltd. is taking proactive action by taking up comprehensive RMU of the Project for revival and life extension of the project.

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The 90% dependable year was computed on the basis of yearly (average) discharge data for the period April 1993 to March 2012 and then the Design Energy was computed on the basis of 10 daily discharge data of the dependable year. The Design Energy computed on this basis is 256.7 MU. Keeping in view the long operational life of the project, it is proposed that Design Energy for Ramganga Power Station may be considered as 256.7 MU. However, after completion of the proposed RMU works of the Project, UJVN Ltd. shall approach the Commission to revise the Design Energy of the Project.

6.10.11.2 NAPAF

NAPAF for Ramganga Power Station computed on the basis of the principle prescribed by UERC has been found to be 19%. For reasons stated above the prescribed principles are not applicable to this Power Station and therefore this figure does not represent the operational efficiency of the plant. Plant Availability computed on the basis of availability of units for generation (irrespective of scheduling of water release) during last five years is around 85%. In this context UERC is requested to prescribe principles for determination of NAPAF for Ramganga Power Station. Till the time such principles are notified NAPAF for Ramganga may be taken as 85%.

6.10.11.3 Auxiliary Consumption and Transformation Losses

These auxiliary consumption and transformation losses together are around 1.6% and more than the limit of 0.7% prescribed by UERC for Surface hydroelectric power generating stations with rotary excitation system. However these losses are expected to be within the limit prescribed by UERC after RMU works.

6.10.12 Impact of Proposed RMU during control period

6.10.12.1 The proposed RMU works are likely to result in (i) Extension of the Plant life by around 25 years (ii) Higher Plant Availability (iii) Increased operating efficiencies of

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plant. The RMU works for the plant is likely to be completed during the control period. The unit wise schedule for implementing RMU is as given in table below:

Name of Date of Start Date of Unit Commissioning Unit-1 15-06-2014 28-02-2015 Unit-2 15-06-2015 28-02-2016 Unit-3 15-06-2016 28-02-2017

6.10.13 Impact of RMU works on Energy generation

6.10.13.1 The proposed RMU of Ramganga Power Station is likely to result in increased plant availability, increased plant capacity and refurbishment of turbines and generators is likely to result in increased efficiencies. Primary purpose of RMU is life extension of the project apart from increase in generation. After RMU, generation will increase from 283 MU to 450 MU (as per DPR) corresponding to 363/364m dam level at the end of filling period subject to releases by UP irrigation department.

6.10.14 Availability

6.10.14.1 The annual maintenance schedule and the RMU schedule proposed for Ramganga Power Station under RMU works for the Control period is as given in the table below:

FY2013-14

Unit No. Start Date End date Days Reasons 1 21-07-2013 08-09-2013 50 Annual Maintenance 2 21-08-2013 09-10-2013 50 Annual Maintenance 3 21-06-2013 09-08-2013 50 Annual Maintenance FY2014-15

Unit No. Start Date End date Days Reasons 1 15-06-2014 28-02-2015 259 RMU 2 21-08-2014 09-10-2014 50 Annual Maintenance 3 21-06-2014 09-08-2014 50 Annual Maintenance

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FY2015-16

Unit No. Start Date End date Days Reasons 1 15-7-2015 28-8-2015 45 Annual Maintenance 2 15-06-2015 28-02-2016 259 RMU 3 21-06-2015 09-08-2015 50 Annual Maintenance

6.10.14.2 The plant availability during the control year considering maintenance schedule given above and forced outages expected (based on past data) during monsoon months is expected to be as given in the table below:

Particulars Base Year FY 2013-14 FY 2014-15 FY 2015-16 Plant Availability (%) 85% 86.3% 67.2% 67.8% The plant availability expected post RMU is likely to be around 87 %.

6.10.15 Auxiliary Consumption and Transformation losses

6.10.15.1 The auxiliary consumption and transformation losses which are currently higher than the limit prescribed by UERC are likely to achieve the prescribed norms after the completion of RMU works.

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6.11 TECHNICAL REPORT OF MANERI BHALI – II HYDROELECTRIC PROJECT

6.11.1 Introduction

6.11.1.1 Maneri Bhali Hydroelectric Project II with an installed capacity of 304 MW (4X76 MW) envisages the utilization of head available in the river Bhagirathi between the tail waters of Maneri Bhali Stage I and Stage II Projects. In Maneri Bhali Stage II Project, water is diverted through a barrage at Joshiyara situated near the township of Uttarkashi at about 152 Km from Rishikesh, the nearest railhead. The barrage is designed to divert 142 cumecs of water into a head race tunnel of diameter 6.0 m and length 16 km to generate electricity through a Power Station of 4X76 MW constructed at Dharasu village.

6.11.1.2 The Power Station comprises of four hydro power generating units of 76 MW each. The generator is powered by Francis turbines of 78 MW rated capacity. The rated flow through each turbine is 35.5 cumecs and is discharged to a common tail race channel.

6.11.2 Determination of Design Energy

6.11.2.1 The Design Energy for all other Power Stations (except for Ramganga Power Station) has been computed considering two approaches. (i) On the basis of average of 10 daily discharges and (ii) the maximum generation possible from the Power Station considering that there were no machine and other outages. The Design Energy for Ramganga has been computed using the first approach only. These approaches considered are probabilistic approaches and for acceptable outcome these requires data of reasonable sample size. This condition is not met in the case of Maneri Bhali-II which has been commissioned in March 2008 only. The Design Energy for Maneri Bhali Stage-II is 1566 MUs, but this DE was calculated considering total installed capacity of Power Station and attainment of full barrage level of 1108 m. Presently, due to restriction of reservoir level of 1104 m at Joshiyara Barrage instead of designed maximum level of 1108 m, the peaking

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capacity has reduced. However after completion of required essential civil works at barrage and modification of Tail Race Channel, it is expected that Power Station will be able to attain its Design Energy.

6.11.2.2 Due to restriction of barrage level and improper evacuation of water through TRC, presently the capacity of the plant has been restricted to 280 MW. As such, it is recommended that till the proposed civil works are completed, Design Energy of Maneri Bhali Stage II HEP for the Control Period be considered as average of annual generation of past four years. After, completion of Civil works at barrage and modification of TRC of Power Station, UJVN Ltd. shall approach the Hon’ble Commission for revision in Design Energy of Maneri Bhali Stage II HEP.

6.11.3 Determination of NAPAF

6.11.3.1 The actual average plant availability during the last four years is given in the table below:

Table 155: Plant Availability during FY 2008-12 – Maneri Bhali - II Hydroelectric Project Sr. No (1) Month (2) Total Reserve Forced Planned Maintenance Total hours Plant Running Outage Outage Annual Capital (max) Availability Hrs. of all (Hrs.) (4) (Hrs.) (5) Mainten Major (Hrs.) (8) % (9) the units ance repairs (Hrs.) (Col. 3+Col. (Hrs.) (3) (Hrs.) (6) (7) 4)/Col.8 1 April 4998 2291 925 3306 0 11520 63% 2 May 9031 1673 122 754 326 11904 90% 3 June 10084 838 598 0 0 11520 95% 4 July 9611 1148 1086 60 0 11904 90% 5 August 6650 3452 942 860 0 11904 85% 6 Sept 9106 1352 346 716 0 11520 91% 7 Oct 8459 2470 323 653 0 11904 92% 8 Nov 5431 3482 122 2486 0 11520 77% 9 Dec 4188 2572 300 4845 0 11904 57% 10 Jan 3385 2991 0 5529 0 11904 54% 11 Feb 2836 2882 74 5057 0 10848 53% 12 March 3684 2690 1664 3866 0 11904 54% Total 77460 27838 6501 28131 326 140256 75%

6.11.3.2 The average plant availability of Maneri Bhali Stage-II HEP during last four years is around 75%.The Maneri Bhali Stage II Hydro Electric Project experiences forced

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shut downs during the monsoon seasons. The reasons for these forced shut downs have been provided in the section below.

6.11.4 Special Circumstances and Abnormal Operating Conditions

6.11.4.1 Since its commissioning, the Power Station operates on base load during monsoon and as a peaking station as per the instructions of SLDC during non-monsoon period when discharge in the river reduces and Power Station has to be run on part capacity. This Power Station meets evening and morning peaks during lean discharge period. But due to restriction of reservoir level to be kept 1104 m at Joshiyara Barrage instead of designed maximum level of 1108 m, the peaking capacity has reduced. However, after completion of required essential civil works at barrage and modification of Tail Race Channel by 2014-2015, peaking capacity will improve and four hours each of evening and morning peaks will be possible.

6.11.4.2 Due to restriction of barrage level and improper evacuation of water through TRC, the capacity of the plant has been restricted to 280 MW. Study of the available inflow data revealed that the maximum capacity can be generated between May to September and partially between October to April. Lean discharge period is utilised for planned annual or capital maintenance.

6.11.5 Plant Outages and Breakdowns

6.11.5.1 Apart from above facts, when flood recedes lot of silt having substantial quartzite particles are lodged in cavities and caves on both banks of river which gets dislodged when level of river starts rising as a result of snow melting during summer season and is carried to the machines through water conductor system causing severe damage to under water parts and frequent plant outages which becomes beyond control of UJVN Limited.

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Business Plan of UJVN Limited for Control Period

6.11.5.2 The forced outage data for the period 2008-2012 has revealed that 58% of the total energy loss is on this account. The table below provides the details.

Table 156: % Generation Loss on account of various Factors – Maneri Bhali - II Hydroelectric Project Sr. No. Month↓ B/D of Flushing & System Flood Total Equipment Choking Condition passing & (in MU) (in MU) (in MU) & Grid fail Any Other (in MU) Reasons (in MU) 1 April 0.00 0.71 0.26 2.72 3.69 2 May 10.16 4.99 3.32 2.50 20.97 3 June 32.82 8.33 15.06 7.01 63.20 4 July 71.15 20.46 3.81 5.25 100.67 5 August 50.18 8.84 0.07 11.29 70.37 6 September 20.41 6.21 1.24 31.04 58.90 7 October 2.73 0.61 1.36 2.78 7.48 8 November 0.00 0.00 0.00 0.00 0.00 9 December 0.02 0.00 0.00 0.66 0.69 10 January 0.00 0.00 0.00 0.00 0.00 11 Feburary 0.00 0.00 0.00 0.00 0.00 12 March 0.00 0.00 0.00 0.00 0.00 Total 187.46 50.16 25.11 63.25 325.98 Energy Lost 58% 15% 8% 19% 100%

6.11.6 Auxiliary Consumption and Transformation Losses

6.11.6.1 The analysis of auxiliary consumption data of past 4 years reveals that the auxiliary consumption of Maneri Bhali Stage II HEP is around 0.35% of the Gross Generation. Similarly the transformation losses of past 4 years for which the data is available has been analysed. The transformation losses are 0.31% of the gross generation. Both auxiliary and transformation losses together constitute around 0.66 % of the Gross Generation.

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Business Plan of UJVN Limited for Control Period

Table 157: Auxiliary and Transformation Losses – Maneri Bhali - II Hydroelectric Project Sr. No Particulars Unit Value 1 Total Gross Generation (2008-12) MUs 4930.10 2 Total Aux. consumption (2008-12) MUs 17.08 3 Aux. consumption as a % of Gross Generation % 0.35% 4 Total Gross Generation (2008-12) MUs 4930.10 5 Total Transformation loss (2008-12) MUs 15.45 6 Transformation loss as a % of Gross Generation % 0.31% 7 Total Aux. and Transformation losses (2008-12) MUs 32.53 Total Aux. and Transformation losses as a % of 8 % 0.66% Gross Generation

6.11.7 Inferences

6.11.7.1 Design Energy

Due to Barrage level restriction and improper evacuation of water through Tail Race Channel of Power Station, Maneri Bhali Stage II HEP is not able to attain its Design Energy. Actions are being taken in this regard by UJVN Ltd. for attainment of Design Energy as stated in the Capex Plan earlier. Maneri Bhali Stage II HEP has been under operation since last four years. Therefore, it is proposed that until the necessary civil works are completed in order to attain Design Energy of the Project, the Primary Energy of Maneri Bhali Stage II HEP be considered as average of last four years generation i.e, 1232.52 MUs.

After completion of the proposed civil works for attainment of Design Energy, the Primary Energy for the Project can be considered w.r.t. original Design Energy of the Project.

6.11.7.2 NAPAF

Based on actual running hours, reserve hours, forced outage hours and plant outage hours for last 4 years average plant availability as calculated in the table 155 is around 75% and this may be taken as NAPAF for Maneri Bhali Stage II HEP for the control period.

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Business Plan of UJVN Limited for Control Period

6.11.7.3 Auxiliary Consumption and Transformation Loss

As explained in the earlier section auxiliary consumption is within the limits set by UERC for underground hydroelectric power generating stations with static excitation system. The same may be considered for the control period.

6.11.8 Projection for the control period

6.11.8.1 As Power Station is recently commissioned, no RMU is planned for Maneri Bhali - II Project. The performance parameters for the control period will be same as forecast provided in the petition.

6.11.9 Availability

6.11.9.1 The annual maintenance schedule proposed for Maneri Bhali-II Power Station during the Control period is as given in the table below:

FY2013-14

Unit No. Start Date End date Days Reasons 1 03-11-2013 01-01-2014 60 Annual Maintenance 2 25-11-2013 23-01-2014 60 Annual Maintenance 3 06-01-2014 06-03-2014 60 Annual Maintenance 4 27-01-2014 27-03-2014 60 Annual Maintenance FY2014-15

Unit No. Start Date End date Days Reasons 1 03-11-2014 01-01-2015 60 Annual Maintenance 2 25-11-2014 23-01-2015 60 Annual Maintenance 3 06-01-2015 06-03-2015 60 Annual Maintenance 4 27-01-2015 27-03-2015 60 Annual Maintenance FY2015-16

Unit No. Start Date End date Days Reasons 1 03-11-2015 01-01-2016 60 Annual Maintenance 2 25-11-2015 23-01-2016 60 Annual Maintenance 3 06-01-2016 05-03-2016 60 Annual Maintenance 4 27-01-2016 26-03-2016 60 Annual Maintenance

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Business Plan of UJVN Limited for Control Period

6.11.9.2 The plant availability during the control year considering maintenance schedule given above and forced outages expected (based on past data) during monsoon months is expected to be as given in the table below:

Particulars Base Year FY 2013-14 FY 2014-15 FY 2015-16 Plant Availability (%) 75% 80% 80% 80%

6.11.10 Auxiliary Consumption and Transformation losses

6.11.10.1 As explained in the earlier section auxiliary consumption is within the limits set by UERC for underground hydroelectric power generating stations with static excitation system. The same may be considered for the control period.

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