UJVNL Business Plan - UERCuerc.gov.in/ordersPetitions/Petitions/2013-14/MYT Petitions and... · Business Plan of UJVN Limited for Control Period 2 TABLE OF CONTENTS 1 INTRODUCTION

Business Plan of UJVN Limited for Control Period

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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


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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


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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 ..................................................................................................................................... 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


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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


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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


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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


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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


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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


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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


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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


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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


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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


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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


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(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


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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.


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1 INTRODUCTION


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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


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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


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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


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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.

N

Power

Station

Installed

Capacity

(MW)

Year of

Commiss

ioning

Type

of

Scheme

River Design

Head

(m)

Design

Discharge

(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


21

S.

N

Power

Station

Installed

Capacity

(MW)

Year of

Commiss

ioning

Type

of

Scheme

River Design

Head

(m)

Design

Discharge

(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

war

0.75 2004 ROR Laxman

ganga

113.00 0.94

18 Jumma 1.20 2005 ROR Jumma

gad

143.50 1.07

19 Tapovan 0.80 2005 ROR Dak

Gadera

274.00 0.41

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

gad

400.00 0.62

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


22

S.

N

Power

Station

Installed

Capacity

(MW)

Year of

Commiss

ioning

Type

of

Scheme

River Design

Head

(m)

Design

Discharge

(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


23

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.


24

Table 4: Planned Capacity Addition by UJVN Limited

S.No. Name of

Project

Estimated

Potential

(MW)

District River/

Tributary

Expected

Commissioning

Year

1 Vyasi 120 Dehradun Yamuna 2016

2 Lakhwar 300 Dehradun Yamuna 2018

3 Bowla

Nandprayag

300 Chamoli Alaknanda 2019

4 Tamak lata 250 Chamoli Dhauliganga 2019

5 Nand Pyayag

Langasu

100 Chamoli Alaknanda 2020

6 Sirkari Bhyol

Rupsiabagar

210 Pithoragarh Goriganga 2021

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


25

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 up-

coming 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


26

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.


27

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


28

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.


29

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


30

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.


31

2 CAPITAL EXPENDITURE PLAN –

UPCOMING PROJECTS


32

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:


33

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

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

Rs.Crores

upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total

Capital Expenditure 104.00 100.00 200.00 200.00 332.23 936.23


34

Table 6: Capital Cost – Vyasi Project

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

VYASI H. E. PROJECT (120 MW), UTTARAKHAND

ABSTRACT OF COST (February 2010)


35

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.


36

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

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

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%


37

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

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total

Capital Expenditure 104.00 100.00 200.00 200.00 332.23 936.23

Capitalization - - - - 936.23 936.23


38

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.


2.2.2.1 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


39

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

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

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 :


40

Table 10: Capital Cost – Lakhwar Project


Crores)

A CIVIL WORKS

1 DIRECT CHARGES

I - Works


B - Land 142.92

C - Works 2,423.90


K - Buildings 62.52

M - Plantation -







TOTAL OF I - WORKS 3,194.31



IV - Suspense -


TOTAL DIRECT CHARGES 3,538.83

2 INDIRECT CHARGES




TOTAL CIVIL WORKS 3,575.54


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

Lakhwar H. E. PROJECT (300 MW), UTTARAKHAND

ABSTRACT OF COST (February 2010)


41



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.


Revised DPR with revised cost estimate based on price level of February, 2010

was submitted to CWC on 16th July, 2010.


42

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.


2.2.3.1 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:


43

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

Rs.Crores

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

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%


2.2.4.1 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


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

Rs.Crores

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

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


44

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.


2.3.2.1 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 :


45

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

Rs.Crores

upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

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 :


46

Table 14: Capital Cost – Kishau Project


Crores)

A CIVIL WORKS

1 DIRECT CHARGES

I - Works


B - Land 800.40

C - Works 4,184.60


K - Buildings 150.11

M - Plantation 3.90










IV - Suspense -



2 INDIRECT CHARGES








KISHAU MULTIPURPOSE H. E. PROJECT (660 MW), UTTARAKHAND

ABSTRACT OF COST (June 2010)


47


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.


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.



Rs. 110 Crores planned for the control period, debt will be Rs. 77 Crores and equity


48

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


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

Rs.Crores

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

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%


2.3.4.1 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

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total

Capital Expenditure - - 10.00 100.00 4,399.00 4,509.00

Capitalization - - - - 4,509.00 4,509.00


49

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.


generate an annual energy of 967.97 MU in a 90% dependable year with 95%

Installed capacity.


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

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total

Capital Expenditure - - - 5.00 888.63 893.63



50

Table 18: Capital Cost – Sirkari Bhyol Rupsiabagar Project


Crores)

A CIVIL WORKS

1 DIRECT CHARGES

I - Works


B - Land 1.80

C - Works 276.50


K - Buildings 17.20

M - Plantation 2.00






Y - Losses on Stock -1.16




IV - Suspense 5.14



2 INDIRECT CHARGES






TOTAL COST (CIVIL + ELECTRICAL) 752.56


FINANCING CHARGES -

TOTAL COST INCLUDING IDC & FINANCING CHARGES 893.63

Total 893.63

ABSTRACT OF COST (June 2003)

SARKARI BHYOL RUPSIABAGAR H. E. PROJECT (210 MW), UTTARAKHAND


51




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).


Project Report.


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.


2.4.3.1 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.


52


table below:

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

Rs.Crores

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

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%


2.4.4.1 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

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total


Capitalization - - - - 893.63 893.63


53

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.


generate an annual energy of 1340 MU in a 90% dependable year with 95% of the

Installed Capacity.


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

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total

Capital Expenditure - 5.00 100.00 200.00 2,702.24 3,007.24



54

Table 22: Capital Cost – Bowala Nand Prayag Project


Crores)

A CIVIL WORKS

1 DIRECT CHARGES

I - Works


B - Land 34.67

C - Works 763.52


K - Buildings 38.66

M - Plantation 0.65










IV - Suspense -



2 INDIRECT CHARGES








FINANCING CHARGES 290.35

TOTAL COST INCLUDING IDC & FINANCING CHARGES 3,007.24

Total 3,007.24

ABSTRACT OF COST (May 2012)

BOWALA NNANDPRAYAG H. E. PROJECT (300 MW), UTTARAKHAND


55


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


Report.


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


56

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.


2.5.3.1 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:


57

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

Rs.Crores

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

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%



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



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

Rs.Crores

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

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


58

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.


generate an annual energy of 490.45 MU in a 90% dependable year with 95% of the

Installed Capacity.


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



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

Rs.Crores

upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total




59

Table 26: Capital Cost – Nand Prayag Langasu Project


Crores)

A CIVIL WORKS

1 DIRECT CHARGES

I - Works


B - Land 3.45

C - Works 228.28


K - Buildings 2.07

M - Plantation 0.18










IV - Suspense -



2 INDIRECT CHARGES








FINANCING CHARGES -

TOTAL COST INCLUDING IDC & FINANCING CHARGES 1,401.19

Total 1,401.19

NANDPRAYAG LANGASU H. E. PROJECT (100 MW), UTTARAKHAND

ABSTRACT OF COST August 2010)


60




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).


Report.


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.


61

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.



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


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

Rs.Crores

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total

Debt - JV - - 3.50 70.00 907.33 980.83

Equity - UJVNL - - 0.39 7.80 101.10 109.29


Debt - JV 0% 0% 70% 70% 70% 70%

Equity - UJVNL 0.00% 0.00% 7.80% 7.80% 7.80% 7.80%



62


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



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

Rs.Crores

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total


Capitalization - - - - 1,401.19 1,401.19


63

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.


2.7.2.1 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



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

Rs.Crores

upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total




64

Table 30: Capital Cost – Tamak Lata Project


Crores)

A CIVIL WORKS

1 DIRECT CHARGES

I - Works


B - Land 19.83

C - Works 198.85


K - Buildings 8.59

M - Plantation 0.95






Y - Losses on Stock -




IV - Suspense -

V- Receipt & Recoveries -


2 INDIRECT CHARGES

I - Capitalised Value of Abatement of Land Revenue -







TAMAKLATA H. E. PROJECT (250 MW), UTTARAKHAND

ABSTRACT OF COST (November 2007)


65

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.


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.



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


66

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

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total

Debt - JV - - 1.40 35.00 701.02 737.42

Equity - UJVNL - - 0.16 3.90 78.11 82.17


Debt - JV 0% 0% 70% 70% 70% 70%

Equity - UJVNL 0.00% 0.00% 7.80% 7.80% 7.80% 7.80%



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

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total


Capitalization - - - - 1,053.45 1,053.45


67

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 submission and clearance

DPR was submitted to CEA/CWC on 04.07.2005, which 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.


68

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

4 Annual Energy Generation( MU)

1406.20

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

8 DPR work & its submission

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 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.

9 Present status of work

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. Total expenditure incurred till date on the project is Rs. 20.92 Crores. Committed liabilities on the Project amounts to Rs. 3.8 Crores.


69

3 CAPITAL EXPENDITURE PLAN –

EXISTING PROJECTS


70

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.


3.1.2.1 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

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total



71

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 :


72

Table 34: Capital Cost – Chibro Project


Crores)

1 DIRECT CHARGES

I - Works


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 -




R - Communication -

S - Power Plant

S1 - Mechanical Equipment 49.63

S2 - Electrical Equipment 77.79






IV - Suspense -



2 INDIRECT CHARGES




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

CHIBRO H. E. PROJECT (240 MW), UTTARAKHAND

ABSTRACT OF COST


73

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.


74


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.


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.


3.1.3.1 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


budgetary support of GoU envisaged for UJVN Limited while debt will be provided


75

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

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

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%


3.1.4.1 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

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total


Capitalization - - - - 184.88 184.88


76

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.










Table 37: Capital Expenditure during Control Period – Khodri Project

Rs.Crores

upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total



77

3.2.2.2 RMU Project



DPR) subject to same water discharge. Details of the total project cost are

provided in the table on the next page :


78

Table 38: Capital Cost – Khodri Project


Crores)

1 DIRECT CHARGES

I - Works


B - Land -

C - Works -

C1 - Civil Works -

C2 - Hydrulic Steel Structures -




K - Buildings -

M - Plantation -




R - Communication -

S - Power Plant








IV - Suspense -



2 INDIRECT CHARGES






IDC 2.51


Up-front Fees -

Guarantee Fees 0.19

Total 169.63

KHODRI H. E. PROJECT (120 MW), UTTARAKHAND

ABSTRACT OF COST


79

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:



benefits;

The Economic Net Present Value (ENPV) which is derived by discounting the

net benefits;



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


EIRR (%) 23.29%


B/C Ratio 2.23


the Khodri Power Station is an economically feasible project. This conclusion is






80


Project Report.





considered that the Financial Analysis data given herein above shall hold good for

the revised execution schedule and the project shall be viable.






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.



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


81

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

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

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%


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

under:






3.2.4.2 Total capital expenditure of Rs. 169.63 Crores will get capitalized after the control


below:

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

Rs.Crores

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total


Capitalization - - - - 169.63 169.63


82

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.






3.3.2.1 Capital Expenditure for RMU works is estimated at Rs. 116.41 Crores.Capital




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

Rs.Crores

upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

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


83

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 :


84

Table 42: Capital Cost – Dhakrani Project


Crores)

1 DIRECT CHARGES

I - Works


B - Land -

C - Works






K - Buildings -

M - Plantation -




R - Communication -

S - Power Plant








IV - Suspense -



2 INDIRECT CHARGES






IDC 2.34


Up-front Fees -

Guarantee Fees 0.18

Total 116.41

DHAKRANI H. E. PROJECT (33.75 MW), UTTARAKHAND

ABSTRACT OF COST


85

3.3.2.3 Economic and Environment Evaluation

The economic feasibility of the RM&U project for the Dhakrani Power Station was




benefits;


benefits;





RESULTS

Site Dhakrani Power

Station


EIRR (%) 25.67%


B/C Ratio 2.88


the Dhakrani Power Station is an economically feasible project. The conclusion is






86


Report.












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.





87



by KfW & PFC. Year-wise allocation of debt and equity for the control period is


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

Rs.Crores

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

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%


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

under:


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


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

Rs.Crores

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total


Capitalization - - - 38.80 77.61 116.41


88

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.










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

Rs.Crores

upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total


3.4.2.2 RMU Project

Financial tie-up for RM&U works of this power station has been done with KfW,




89






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 :


90

Table 46: Capital Cost – Dhalipur Project


Crores)

1 DIRECT CHARGES

I - Works


B - Land -

C - Works -

C1 - Civil Works -





K - Buildings -

M - Plantation -




R - Communication -

S - Power Plant








IV - Suspense -



2 INDIRECT CHARGES






IDC 2.20


Up-front Fees -

Guarantee Fees 0.16

Total 116.81

DHALIPUR H. E. PROJECT (51 MW), UTTARAKHAND

ABSTRACT OF COST


91


The economic feasibility of the M&U project for the Dhalipur Power Station was




benefits;


benefits;





RESULTS

Site Dhalipur Power

Station


EIRR (%) 24.96%


B/C Ratio 2.97


the Dhalipur Power Station is an economically feasible project. The conclusion is






92


Project Report.













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.





93





Table 47: Funding Pattern during Control Period – Dhalipur Project

Rs.Crores

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

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%


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

under:


Unit I 1st October 2014 30th June2015



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


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

Rs.Crores

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total


Capitalization - - - 38.94 77.87 116.81


94

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.










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

Rs.Crores

upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total


3.5.2.2 RMU Project

Financial tie-up for RM&U works of six stations has been done with KfW,




95






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 :


96

Table 50: Capital Cost – Kulhal Project


Crores)

1 DIRECT CHARGES

I - Works


B - Land -

C - Works -






K - Buildings -

M - Plantation -




R - Communication -

S - Power Plant








IV - Suspense -



2 INDIRECT CHARGES






IDC 2.38


Up-front Fees -

Guarantee Fees 0.18

Total 118.72

KULHAL H. E. PROJECT (30 MW), UTTARAKHAND

ABSTRACT OF COST


97


The economic feasibility of the M&U project for the Kulhal Power Station was




benefits;


benefits;





RESULTS

Site Kulhal Power

Station


EIRR (%) 20.57%


B/C Ratio 2.12


the Kulhal Power Station is an economically feasible project. The conclusion is






98


Project Report.













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..







99



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

Rs.Crores

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

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%


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

under:


Unit I 1st October 2014 30th June 2015



3.5.4.2 Out of total capital expenditure of Rs. 41.55 Crores, Rs 39.57 Crores will get



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

Rs.Crores

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total


Capitalization - - - 39.57 79.15 118.72


100

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.









is shown in the table on the next page :


101

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

Rs.Crores

upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total

Capital Expenditure - 18.93 25.25 44.18 37.87 126.23

3.6.2.2 RMU Project



DPR) subject to same water discharge. Details of the total project cost are



102

Table 54: Capital Cost – Tiloth Project


Crores)

1 DIRECT CHARGES

I - Works


B - Land -

C - Works






K - Buildings -

M - Plantation -




R - Communication -

S - Power Plant








IV - Suspense -



2 INDIRECT CHARGES






IDC 2.53


Up-front Fees -

Guarantee Fees 0.19

Total 126.23

TILOTH H. E. PROJECT (90 MW), UTTARAKHAND

ABSTRACT OF COST


103

3.6.2.3 Economic and Environment Impact Evaluation:

The economic feasibility of the RM&U project for the Tiloth Power Station was




benefits;


benefits;





RESULTS

Site Tiloth Power

Station


EIRR (%) 29.28%


B/C Ratio 2.87


the Tiloth Power Station represents an economically feasible project. The

conclusion is drawn due to the following observations:





104


Project Report.













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.







105

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

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

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%


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

under:





3.6.4.2 Out of total capital expenditure of Rs. 88.36 Crores, Rs. 84.15 Crores will get



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

Rs.Crores

Year upto

31.03.2013 FY 2013-

14 FY 2014-

15 FY 2015-

16 after

31.03.2016 Total


Capitalization - - 42.08 42.08 42.08 126.23


106

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.


3.7.2.1 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


3.7.2.2 RMU Project


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


107

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 :


108

Table 58: Capital Cost – Chilla Project


Crores)

1 DIRECT CHARGES

I - Works

A - Preliminary -

B - Land -

C - Works

C1 - Civil Works -





K - Buildings -

M - Plantation -

O - Miscellaneous -

P - Maintenance During Construction -


R - Communication -

S - Power Plant



X - Environment and Ecology -

Y - Losses on Stock -


II - Establishment

III - Tools and Plants

IV - Suspense -



2 INDIRECT CHARGES


II - Audit & Accounts Charges -

TOTAL INDIRECT CHARGES -


Escalation till start of M&U Measure

IDC 37.00

Commitment Fees -

Up-front Fees -

Guarantee Fees -

Total 337.00

CHILLA H. E. PROJECT (144 MW), UTTARAKHAND

ABSTRACT OF COST


109

3.7.2.3 Economic and Environment Impact Evaluation:

The economic feasibility of the RM&U project for the Chilla Power Station was




benefits;


benefits;





RESULTS

Site Chilla Power

Station


EIRR (%) 24.74%


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:





110


Project Report.


been provided in the Detailed Project Report.


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.



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.


table below:


111

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%


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

under:






3.7.4.2 Total Capex will get capitalized after the control period. Year-wise capitalization


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

Rs. Crores



Capitalization - - - - 337.00 337.00


112

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.






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

Rs. Crores


Capital Expenditure 49.40 84.28 60.82 25.94 - 220.44

3.8.2.2 RMU Project


generation. After RMU, generation will increase from 149.03 MU to 235 MU (as


113

per DPR) subject to same water discharge. Details of the total project cost are



114

Table 62: Capital Cost – Khatima Project


Crores)

1 DIRECT CHARGES

I - Works


B - Land -

C - Works

C1 - Civil Works -





K - Buildings -

M - Plantation -

O - Miscellaneous -


Q - Special Tools and Plants -

R - Communication -

S - Power Plant

S1 - Mechanical Equipment

S2 - Electrical Equipment






IV - Suspense -



2 INDIRECT CHARGES





Escalation till start of M&U Measure -

IDC 35.14

Commitment Fees -

Up-front Fees -

Guarantee Fees -

Total 220.44

ABSTRACT OF COST

KHATIMA H. E. PROJECT (41.40 MW), UTTARAKHAND

129.50


115

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:



benefits;


benefits;





RESULTS

Site Khatima Power

Station


EIRR (%) 11.32%


B/C Ratio 1.18


116

These results lead to the conclusion that the modernization and upgrading of the

Khatima Power Station is an economically feasible project. The conclusion is






Project Report.




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


3.8.3.1 The Project is being financed with the Debt: Equity ratio of 70:30. Out of Capex of



117


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


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%


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

under:


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


below:

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

Rs. Crores


Capital Expenditure 49.40 84.28 60.82 25.94 - 220.44

Capitalization - - 146.96 73.48 - 220.44


118

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.





is shown in the table on the next page :


119

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

Rs. Crores



3.9.2.2 RMU Project



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 :


120

Table 66: Capital Cost – Ramganga Project


Crores)

1 DIRECT CHARGES

I - Works


B - Land -

C - Works






K - Buildings -

M - Plantation -

O - Miscellaneous -

P - Maintenance During Construction -

Q - Special Tools and Plants -

R - Communication -

S - Power Plant








IV - Suspense -



2 INDIRECT CHARGES





Escalation till start of M&U Measure -

IDC 94.38

Commitment Fees -

Up-front Fees -

Guarantee Fees -

Total 455.22

RAMGANGA H. E. PROJECT (198 MW), UTTARAKHAND

ABSTRACT OF COST


121

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:



benefits;


benefits;





RESULTS

Site Ramganga Power

Station


EIRR (%) 12.97%


B/C Ratio 1.41


the Ramganga Power Station represents an economically feasible project. The

conclusion is drawn due to the following observations:





122


Project Report.




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.





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


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%


123


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

under:


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



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

Rs. Crores



Capitalization - - 151.74 151.74 151.74 455.22


124

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.


125


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



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

Rs. Crores


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:


126

Table 70: Capital Cost – Maneri Bhali - II Project


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

conduit on left Bank (1.2 km) and from Barrage to NH-108 on

Right Bank (0.4 km)

2.22

8 Balance infrastructure works for affected villages of

Joshiyara, Gyanshu & Kansain as per their demands

9.50

9 Construction of boundary wall, sectrity fencing and gate for

Shaktipuram colony and Shifting of existing boundary wall

of Shaktipuram colony and provide the separate way for

villagers behind Shaktipuram colony

1.21

10 Construction of 04 Nos Type-IV Residences and 01 Nos Type-

V Residence in Shaktipuram colony, Chinyalisaur

1.10

11 Construction of school building for Saraswati Shishu Mandir

School in Shaktipuram Colony Chinyalisaur

2.00

12 Strengthening of water distribution system of Shaktipuram

colony, Chinyalisaur

0.89

13 Construction of workshop building at Dharasu power house

of MB-II project

1.69

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

in accordance to the decision of High Power Committee

12.68

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

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

30.73

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

MANERI BHALI - II H. E. PROJECT (304 MW), UTTARAKHAND

ABSTRACT OF COST



Rs. 191.23 Crores planned during the control period, debt will be Rs. 133.86


127

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


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%


3.10.4.1 Total capital expenditure of Rs. 191.23 Crores will get capitalized during the control


below:

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

Rs. Crores


Capital Expenditure 25.00 100.00 91.23 - 216.23

Capitalization 25.00 100.00 91.23 - - 216.23


128

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


129

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.


130

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


131

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.


132

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


133

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



provided as grant for this project.


134

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


135

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




provided as grant to the project.


136

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


137

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




provided as grant to the project.


138

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.


139

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.


140

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


141

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. No.

Name of Work Amount FY14 FY15 Sources

1 Refurbishment of Asan Barrage, at Dhalipur (Dehradun)

535.32 214.13 321.19 Grant under DRIP Scheme

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

2237.57 895.03 1342.54

3 Rehabilitation Work of Virbhadra Barrage, Pashulok, Rishikesh.

625.81 250.32 375.49

4 Refurbishment of Dakpathar Barrage, at Dakpathar (Dehradun)

672.21 268.88 403.33

5 Refurbishment of Maneri Dam at Maneri, Uttrakashi

453.24 181.30 271.94

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

1673.15 1673.15 Debt Equity ratio of 70:30 7 Closure of Chilla HEP for Special Repair of

Power Channel, Submerged Parts Of Structures & Hydro-Mechanical Components of Virbhadra Barrage, Pashulok, Rishikesh.

645.00 645.00

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


142

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.


143

4 MAJOR SHUTDOWN PLAN OF POWER

STATIONS


144

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


145

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


146

5 SUMMARY


147

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


148

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


149

6 TECHNICAL REPORT OF EXISTING

POWER STATIONS


150

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


151

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


152

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

For calculation of power following formula has been used:

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

Sl. No. 10 Daily

Discharge

Average

Year %

Dependability

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%


153

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:


154

Table 78: Discharge & Generation Data – Tiloth Power Station

Sr.no. Month Net Discharge

(cumecs)

Net Head

(meter)

Power Potential

(kW)

Energy (kWh)

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

39,47,68,006.1 Annual Energy Generation


155

Table 79: Design Energy: Tiloth Power Station

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

(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

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%

Sr. No % losses B/D of

Equipment

(1)

Flushing &

Choking

(2)

System

Condition

(3)

Flood

Passing &

Any Other

Reason (4)

Total (5)

1

Gross losses as % of Max.

Grosss Generation 2.1% 5.5% 0.3% 0.3% 8.2%

2

Losses due to uncontrollable

factors (5)-(1) 6.1%


156

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:


157

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

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

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:

Sr. no. Actual Gross

Generation

(MU)

Generation

Loss (MU)

Maximum

Possible

Generation

(MU)

Year %

Dependabi

lity

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

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


158

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

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

Annual

Mainten

ance

(Hrs.) (6)

Capital

Major

repairs (Hrs.)

(7)

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%

Planned Maintenance Total

hours(max)

(Hrs.) (8)

Plant

Availability

% (9)

(Col. 3+Col.

4)/Col.8

Month (2)Sr. No (1) Total

Running

Hrs. of all

the units

(Hrs.) (3)

Reserve

Outage

(Hrs.) (4)

Forced

Outage

(Hrs.) (5)


159

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.


160

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

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

Sr. No. Month↓ B/D of

Equipment

(in MU)

Flushing &

Choking

(in MU)

System

Condition

& Grid fail

(in MU)

Flood

passing &

Any Other

Reasons

(in MU)

Total

(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%


161

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

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.

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

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%


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

8Total Aux. and Transformation losses as a % of

Gross Generation% 1.0%

Sr. No Year Transformation

& line losses

Auxiliary

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%


162

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


163

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

Unit

Date of Start Date of

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:


164

FY2013-14

Unit No. Start Date End date Days Reasons

1 01-11-2013 31-03-2015 516 RMU

15-07-2013 31-07-2013 17Interim repair of spherical

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

15-07-2013 30-08-2013 47

Major repair of Unit-3

(15/7/13 to 30/8/14), Major

repair of Spherical Valve of

Unit-3 (15/7/13 to 15/8/13)

2

3

FY2014-15


1 01-11-2013 31-03-2015 516 RMU

15-07-2014 30-08-2014 47Major repair of Unit 2

(15/7/14 to 30/8/14)

15-01-2015 31-01-2015 17 Interim repair of Unit-2

15-07-2014 31-07-2014 17

Interim repair of Unit 3,

Interim repair of

spherical valve of Unit 3

15-11-2014 14-12-2014 30 Repair of Unit-3

2

3

FY2015-16


1 01-12-2015 30-12-2015 30

Interim repair of of Unit

1, Interim repair of


2 01-06-2015 31-03-2016 305 RMU

01-01-2016 30-01-2016 30 Interim repair of Unit 3

15-07-2015 31-07-2015 17

Interim repair of Unit 3,

Interim repair of


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 %.


165

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.


166

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


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.


6.3.2.1 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


167

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.


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

Average

Discharge

Year %

Dependability

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


168




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


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.




169

Table 87: Discharge & Generation Data – Chibro Power Station

Sl.no. Month Net Discharge

(cumecs)

Net Head

(meter)

Power Potential

(kW)

Energy (kWh)

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

611364477Annual Energy Generation


170

Table 88: Design Energy- Chibro Power Station


during the period for which data is available) reduction in the energy




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 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


Equipment

(1)

Flushing &

Choking

(2)

System

Condition

(3)

Flood

Passing &

Any Other

Reason (4)

Total (5)

1

Gross lossesas a % of Max

Gross Generation 1.54% 2.44% 0.30% 1.41% 5.69%

2

Losses due to Uncontrollable

factor (5)-(1) 4.15%


171



additional generation lost by UJVN Limited) is on account of (i) Equipment

break down (ii) Flushing and Choking (iii) System Condition (iv) Flood passing


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





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


Generation

(MU)

Generation

Loss (MU)

Maximum

Power

Generation

(MU)

Year %

Dependabi

lity

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


172


dependable year, the Design Energy for the Chibro Power Station is

computed to be 628.18 MUs.

Table 91: Design Energy – Chibro Power Station


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

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%.




3 Plant Availability for FY 04-05 % 77.92




Annual

Mainten

ance

(Hrs.) (6)

Capital

Major

repairs (Hrs.)

(7)

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%

Planned Maintenance Total hours

(max)

(Hrs.) (8)

Plant

Availability

% (9)

(Col. 3+Col.

4)/Col.8

Sr. No (1) Month (2) Total

Running

Hrs. of all

the units

(Hrs.) (3)

Reserve

Outage

(Hrs.) (4)

Forced

Outage

(Hrs.) (5)


173


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.


6.3.6 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.




174

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


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


Equipment

Flushing &

Choking

System

Condition

& Grid fail

Flood

passing &

Any Other

Reasons

Total

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%









8Total Aux. and Transformation losses as % of



175


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.

6.3.8 Inferences


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.


& line losses

Auxiliary

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%


176

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


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%.


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.


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.


6.3.9.1 RMU works are proposed for the Chibro Power Station. The proposed RMU works






177

Name 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


6.3.10.1 Primary purpose of RMU is life extension of the project apart from increase in


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


FY 2013-14


1 01-11-2013 10-12-2013 40 Annual Maintenance




FY 2014-15






FY 2015-16


1 01-11-2015 31-03-2017 517 RMU





178


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%.


6.3.12.1 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.


179

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.


operations of machines for the past 46 years, efficiency of machines has


even in spite of best and timely maintenance and adoption of effective operational

strategy.


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


/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


180

the project, Design Energy and NAPAF have been calculated on the basis of



Reliable 10 daily (average) discharge data for Dhakrani Power Station is


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




UJVN Limited. Design energy estimation is sensitive to these assumptions.

Sr. No. 10 Daily

Average

Discharge

Year %

Dependability

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


181

The plant has been in operation for past 46 years and it is quite possible that



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.




182

Table 96: Discharge & Generation Data – Dhakrani Power Station


(cumecs)

Net Head

(meter)

Power Potential

(kW)

Energy (kWh)

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



183

Table 97- Design Energy: Dhakrani Power Station


during the period for which data is available) reduction in the energy




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

(ii) On the basis of Maximum Possible Plant generation





2 Energy loss during monsoon and forced outages kWh 9633453.9


4 Design Energy (MU) MUs 122.5



Equipment

(1)

Flushing

&

Choking

(2)

System

Condition

(3)

Flood

Passing &

Any Other

Reason (4)

Total (5)

1

Gross losses as % of Max


2


factors (5)-(1) 7.3%


184



additional generation loss to UJVN Limited) is on account of (i) Equipment

break down (ii) Flushing and choking (iii) System Conditions (iv) Flood passing



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




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


Generation

(MU)

Generation

Loss (MU)

Maximum

Possible

Generation

(MU)

Year %

Dependabi

lity

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


185

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


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

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.








Annual

Mainten

ance

(Hrs.) (6)

Capital

Major

repairs (Hrs.)

(7)

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%

Plant

Availability

% (9)

(Col. 3+Col.

4)/Col.8


Running

Hrs. of all

the units

(Hrs.) (3)

Reserve

Outage

(Hrs.) (4)

Forced

Outage

(Hrs.) (5)


(max)

(Hrs.) (8)


186


6.4.4.1 Since its commissioning, Dhakrani Power Station operates on base load during



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


availability.


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.


187

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



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.


Equipment

(in MU)

Flushing &

Choking

(in MU)

System

Condition

& Grid fail

(in MU)

Flood

passing &

Any Other

Reasons

(in MU)

Total

(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%


188

Table 103: Auxiliary and Transformation Losses – Dhakrani Power Station




6.4.7 Inferences


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





1 Total Gross Generation 1997-12) MUs 2157.79




& line losses

Auxiliary

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%


189

equipments is deteriorating with passage of time. UJVN Ltd. is taking proactive




Energy for Dhakrani Power Station may be considered as 119.38 MU which is the




6.4.7.2 NAPAF


for run of the river plant. Based on the principle given by UERC the annual plant

availability has been calculated in earlier table 97 which comes to 83.5%.


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.


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.


190


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

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


6.4.9.1 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


FY2013-14





FY2014-15


191


1 01-10-2014 30-06-2015 273 RMU



FY2015-16



2 01-10-2015 30-06-2016 274 RMU


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%.





be adopted. The Dhakrani Power Station is expected to achieve normative auxiliary

consumption and transformation loss level after completion of RMU works.


192

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


even in spite of best and timely maintenance and adoption of effective operational

strategy.


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


193

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



Reliable 10 daily (average) discharge data for Dhalipur Power Station is



(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

Average

Discharge

Year %

Dependability

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


194








generator and turbine of Dhalipur Power Station UJVN Limited for the



much lower than the designed values.




195

Table 105: Discharge & Generation Data – Dhalipur Power Station


(cumecs)

Net Head

(meter)

Power Potential

(kW)

Energy (kWh)

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



196

Table 106: Design Energy- Dhalipur Power Station


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 Parameter Unit Value







Equipment

(1)

Flushing &

Choking

(2)

System

Condition

(3)

Flood

Passing &

Any Other

Reason (4)

Total (5)

1



2


factors (5)-(1) 5.01%


197


considering data available since 1998-99. The loss of generation (possible





energy that Dhalipur Power Station possibly could have generated (with 100%









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


Generation

(MU)

Generation

Loss (MU)

Maximum

Possible

Generation

(MU)

Year %

Dependabi

lity

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


198


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



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

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%.








Annual

Mainten

ance

(Hrs.) (6)

Capital

Major

repairs (Hrs.)

(7)

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%

Plant

Availability

% (9)

(Col. 3+Col.

4)/Col.8


Running

Hrs. of all

the units

(Hrs.) (3)

Reserve

Outage

(Hrs.) (4)

Forced

Outage

(Hrs.) (5)


(max)

(Hrs.) (8)


199


6.5.4.1 Since its commissioning, Dhalipur Power Station operates on base load during



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.


generated between May to September and partially between October to April.



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.





200

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



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


Equipment

(in MU)

Flushing &

Choking

(in MU)

System

Condition

& Grid fail

(in MU)

Flood

passing &

Any Other

Reasons

(in MU)

Total

(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%


201

Table 112: Auxiliary and Transformation Losses – Dhalipur Power Station




6.5.7 Inferences


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



1 Total Gross Generation 1998-12) MUs 3089.55










& line losses

Auxiliary

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%


202







Energy for Dhalipur Power Station may be considered as 182.23 MU which is the




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%.


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.



hydroelectric power generating stations with rotary excitation system by 1.24%.



6.5.8 Projections for the Control Period


203

6.5.8.1 RMU works are proposed for the Dhalipur Power Station. The proposed RMU works





Name 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


6.5.9.1 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


FY2013-14






204

FY2014-15


1 01-10-2014 30-06-2015 273 RMU



FY2015-16



2 01-10-2015 30-06-2016 274 RMU








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 %.





be adopted. The Dhalipur Power Station is expected to achieve normative loss level

after completion of the RMU works.


205

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



206

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.


6.6.2.1 Khodri power Station is a run of the river Power Station. For computing the Design


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


/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.


Reliable 10 daily (average) discharge data for Khodri Power Station is



(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:


207

Table 113: 90% Dependable year – Khodri Power Station



considered as 0.969and 0.925 as per the past design records available with





generator and turbine of Khodri Power Station, UJVN Limited for the present


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:

Sl. No. 10 Daily

Discharge

Average

Year %

Dependability

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


208

Table 114: Discharge & Generation Data – Power Station


(cumecs)

Net Head

(meter)

Power Potential

(kW)

Energy (kWh)

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



209

Table 115: Design Energy-Khodri Power Station






silting during flash floods, flood passing and grid failure. These losses






1999-00 to 2011-12. The details of these losses are provided in the table

below:

Table 116: Uncontrollable Losses – Khodri Power Station











Equipment

(1)

Flushing &

Choking

(2)

System

Condition

(3)

Flood

Passing &

Any Other

Reason (4)

Total (5)

1



2


factors (5)-(1) 3.42%


210

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


Generation

(MU)

Generation

Loss (MU)

Maximum

Possible

Generation

(MU)

Year %

Dependabi

lity

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


211


90% dependable year, the Design Energy for the Khodri Power Station is


Table 118: Design Energy – Khodri Power Station



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

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%.








Annual

Mainten

ance

(Hrs.) (6)

Capital

Major

repairs (Hrs.)

(7)

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%

Plant

Availability

% (9)

(Col. 3+Col.

4)/Col.8


Running

Hrs. of all

the units

(Hrs.) (3)

Reserve

Outage

(Hrs.) (4)

Forced

Outage

(Hrs.) (5)


(max)

(Hrs.) (8)


212


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.




6.6.4.3 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


availability.






causing severe damage to under water parts and frequent plant outages which

becomes beyond control of UJVN Limited




213

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


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.


Equipment

(in MU)

Flushing &

Choking

(in MU)

System

Condition

& Grid fail

(in MU)

Flood

passing &

Any Other

Reasons

(in MU)

Total

(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



214

Table 121: Auxiliary and Transformation Losses – Khodri Power Station




6.6.7 Inferences


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%.


to the earlier table 118) which comes to 301.15 MU.

Khodri Power Station is quite old Power Station and has been under operation













& line losses

Auxiliary

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%


215







Energy for Khodri Power Station may be considered as 301.15 MU which is the




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%.


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.


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.



216

6.6.8.1 RMU works are proposed for the Khodri Power Station. The proposed RMU works





Name 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


6.6.9.1 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



to same water discharge.

6.6.10 Availability

6.6.10.1 The annual maintenance schedule and the RMU schedule proposed for Khodri


2013-14






2014-15


217






2015-16


1 01-11-2015 31-03-2017 517 RMU





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:









218

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.


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.


6.7.2.1 Kulhal Power Station is a run of the river plant. For computing the Design Energy


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


219

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.


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



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

Sl. No. 10 Daily

Discharge

Average

Year %

Dependability

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


220

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



much lower than designed values.




221

Table 123: Discharge & Generation Data – Kulhal Power Station


(cumecs)

Net Head

(meter)

Power Potential

(kW)

Energy (kWh)

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



222

Table 124: Design Energy-Kulhal Power Station












2001-12. The details of these losses are provided in the table below:

Table 125: Uncontrollable Losses – Kulhal Power Station



option of computing Design Energy on the basis of actual gross generation

and generation lost on account of various operational & Hydrological reasons



2 Energy loss during monsoon and forced outages kWh 70,09,640.9

3 Design Energy kWh 12,39,44,219.1




Equipment

(1)

Flushing &

Choking

(2)

System

Condition

(3)

Flood

Passing &

Any Other

Reason (4)

Total (5)

1



2


factors (5)-(1) 5.35%


223

for which the data is available since 2001-02. The loss of generation (possible





energy that Kulhal Power Station possibly could have generated (with 100%



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




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


90% dependable year, the Design Energy for the Kulhal Power Station is



Generation

(MU)

Generation

Loss (MU)

Maximum

Possible

Generation

(MU)

Year %

Dependabi

lity

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


224

Table 127: Design Energy – Kulhal Power Station


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

6.7.3.2 The availability plant availability during this period is around 88%.


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








Annual

Mainten

ance

(Hrs.) (6)

Capital

Major

repairs (Hrs.)

(7)

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%

Plant

Availability

% (9)

(Col. 3+Col.

4)/Col.8


Running

Hrs. of all

the units

(Hrs.) (3)

Reserve

Outage

(Hrs.) (4)

Forced

Outage

(Hrs.) (5)


(max)

(Hrs.) (8)


225

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



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



availability.




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



Equipment

(in MU)

Flushing &

Choking

(in MU)

System

Condition

& Grid fail

(in MU)

Flood

passing &

Any Other

Reasons

(in MU)

Total

(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%


226


auxiliary consumption of Kulhal Power Station is around 0.3% of the Gross


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



UERC, as shown below, shows improvement in auxiliary consumption and


6.7.7 Inferences


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.












& line losses

Auxiliary

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%


227

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%.


the earlier table 127) which comes to 127.55 MU.

Kulhal Power Station is quite old Power Station and has been under operation








Energy for Kulhal Power Station may be considered as 127.55 MU which is the




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.


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.


228



hydroelectric power generating stations with rotating excitation system by 2.4%.



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





Name 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


6.7.9.1 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



to same water discharge

6.7.10 Availability


229

6.7.10.1 The annual maintenance schedule and the RMU schedule proposed for Kulhal


FY2013-14

\





FY2014-15


1 01-10-2014 30-06-2015 273 RMU



FY2015-16



2 01-10-2015 30-06-2016 274 RMU



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:









230

be adopted. The Kulhal Power Station is expected to achieve normative auxiliary

consumption and transformation loss level after completion of the RMU works.


231

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.


6.8.2.1 Chilla Power Station is a run of the river plant. For computing the Design Energy,


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


232

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





The plant has been in operation for 32 years and it is quite possible that



Sr. No. 10 Daily

Average

Discharge

Year %

Dependability

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


233

generator and turbine of Chilla Power Station, UJVN Limited for the present


purpose though the actual efficiency levels are expected to be lower.




234

Table 132: Discharge & Generation Data – Chilla Power Station


(cumecs)

Net Head

(meter)

Power Potential

(kW)

Energy (kWh)

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



235

Table 133: Design Energy: Chilla Power Station






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











5 Plant Availability of 05-06 % 76.4


Equipment

(1)

Flushing &

Choking

(2)

System

Condition

(3)

Flood

Passing &

Any Other

Reason (4)

Total (5)

1



2


factors (5)-(1) 5.6%


236





that Chilla Power Station possibly could have generated (with 100% Unit








year wise generation has been computed in table below:

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


90% dependable year, the Design Energy for the Chilla Power Station is

computed to be 718.98 MUs as given in table 136 below.


Generation

(MU)

Generation

Loss (MU)

Maximum

Possible

Generation

(MU)

Year %

Dependabi

lity

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


237

Table 136: Design Energy – Chilla Power Station


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

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.








Annual

Mainten

ance

(Hrs.) (6)

Capital

Major

repairs (Hrs.)

(7)

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%

Total hours

(max)

(Hrs.) (8)

Plant

Availability

% (9)

(Col. 3+Col.

4)/Col.8


Running

Hrs. of all

the units

(Hrs.) (3)

Reserve

Outage

(Hrs.) (4)

Forced

Outage

(Hrs.) (5)

Planned Maintenance


238


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.


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.






239



becomes beyond the control of UJVN Limited



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



auxiliary consumption of Chilla Power Station is around 0.1% of the Gross


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.


Equipment

(in MU)

Flushing &

Choking

(in MU)

System

Condition

& Grid fail

(in MU)

Flood

passing &

Any Other

Reasons

(in MU)

Total

(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%


240

Table 139: Auxiliary and Transformation Losses – Chilla Power Station

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


6.8.7 Inferences


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%.


Table- 136) which comes to 718.98 MU.












& line losses

Auxiliary

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%


241

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.


Energy for Chilla Power Station may be considered as 718.98 MU which is the




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%.


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%


static excitation system.



242

6.8.8.1 RMU works are proposed for the Chilla Power Station. The proposed RMU works



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

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


6.8.9.1 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


2013-14







243

2014-15


1 01-11-2014 31-03-2016 517 RMU




2015-16


1 01-11-2014 31-03-2016 517 RMU

















244

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.


245

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.


6.9.2.1 Khatima Power Station is a run of the river type plant. For computing the Design


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


/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


246

the project, Design Energy and NAPAF have been calculated on the basis of



Reliable 10 daily (average) discharge data for Khatima Power Station is


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





The plant has been in operation for last 55 years and it is quite possible that



generator and turbine of Khatima Power Station, UJVN Limited for the


Sr. No. 10 Daily

Average

Discharge

Year %

Dependability

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


247


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


(cumecs)

Net Head

(meter)

Power Potential

(kW)

Energy (kWh)

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



248

Table 142: Design Energy- Khatima Power Station







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



2000-12. The details of these losses are provided in the table below:

Table 143: Uncontrollable Losses – Khatima Power Station



option of computing Design Energy on the basis of actual gross generation










Equipment

(1)

Flushing &

Choking

(2)

System

Condition

(3)

Flood

Passing &

Any Other

Reason (4)

Total (5)

1



2


factors (5)-(1) 4.7%


249



and other reasons. UJVNL computes on a daily basis, the generation


that Khatima Power Station possibly could have generated (with 100% Unit








year wise generation has been computed in table below:

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


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;


Generation

(MU)

Generation

Loss (MU)

Maximum

Possible

Generation

(MU)

Year %

Dependabi

lity

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


250

Table 145: Design Energy – Khatima Power Station


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

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


6.9.5.1 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








Annual

Mainten

ance

(Hrs.) (6)

Capital

Major

repairs (Hrs.)

(7)

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%

Sr. No (1) Total hours

(max)

(Hrs.) (8)

Plant

Availability

% (9)

(Col. 3+Col.

4)/Col.8

Month (2) Total

Running

Hrs. of all

the units

(Hrs.) (3)

Reserve

Outage

(Hrs.) (4)

Forced

Outage

(Hrs.) (5)

Planned Maintenance


251

partially between October to April. Lean discharge period is again utilised for

planned annual or capital maintenance.


2000-12 has been calculated in the tables 143 and 147, which is around 3.5% of the



availability.




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

6.9.7



Equipment

(in MU)

Flushing &

Choking

(in MU)

System

Condition

& Grid fail

(in MU)

Flood

passing &

Any Other

Reasons

(in MU)

Total

(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



252


auxiliary consumption of Khatima Power Station is around 0.3% of the Gross


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

6.9.9 Inferences


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













253







Energy for Khatima Power Station may be considered as 152.57 MU which is the




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%.


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.


As explained in the earlier section these losses exceed the limit of 0.7% by 0.1%


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


254

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

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


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


1 01-10-2012 31-03-2014 547 RMU

2 15-12-2013 31-12-2013 17

Interim Maintenance, as

Unit is to be taken under

RMU soon


FY2014-15


255



2 01-04-2014 31-01-2015 306 RMU

3 01-01-2015 31-10-2015 304 RMU

FY2015-16




3 15-02-2016 05-03-2016 20

General inspection,

interim repairs may be

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:





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.


256

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:-


257

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


258

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


259

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.


6.10.6.1 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.


260

Table 149: Annual Discharge

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.

Sr. No Year Full

Reservoir

Level(FRL)

Minimum

Draw Down

Level

(MDDL)

Discharge available

for Generation in M.

Cum

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


261

Table 150: 90% Dependable year

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:

Sr. No. 10 Daily

Average

Discharge

Year %

Dependability

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


262

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

basis


(cumecs)

Net Head

(meter)

Power Potential

(kW)

Energy (kWh)

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

256.7 Annual Energy Generation


263

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.


6.10.7.1 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:


264

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:


265

Table 152: Plant availability based on Peaking Capability

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.

Sr. no. Month Average three

hour Peaking

Capacity

Considering

months of Dec, Jan

, 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

13

Weighted average of

peaking capability39 77

14 Forced Outage 2% 1.5%

15

Expected Average

peaking Capability38 76

16 Installed Capacity 198

17 NAPAF 19% 38%


266

Table 153: Plant Availability during 2007-12

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.


6.10.10.1 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.

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


267

Table 154: Auxiliary and Transformation losses

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:


Ramganga Power Station is quite old Power Station and has been under operation



equipments, thereby causing breakdown of machines. The condition of these

equipments are deteriorating with passage of time. UJVN Ltd. is taking proactive



Sr. no. Year Gross

Generation

(MU)

Auxiliary

Consumption

(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


268

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%.


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


269

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

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





FY2014-15


1 15-06-2014 28-02-2015 259 RMU




270

FY2015-16



2 15-06-2015 28-02-2016 259 RMU




months is expected to be as given in the table below:



The plant availability expected post RMU is likely to be around 87 %.


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.


271

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.


6.11.2.1 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


272

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.


6.11.3.1 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

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

Annual

Mainten

ance

(Hrs.) (6)

Capital

Major

repairs (Hrs.)

(7)

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%


(max)

(Hrs.) (8)

Plant

Availability

% (9)

(Col. 3+Col.

4)/Col.8


Running

Hrs. of all

the units

(Hrs.) (3)

Reserve

Outage

(Hrs.) (4)

Forced

Outage

(Hrs.) (5)


273

shut downs during the monsoon seasons. The reasons for these forced shut downs

have been provided in the section below.


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.







becomes beyond control of UJVN Limited.


274



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



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.


Equipment

(in MU)

Flushing &

Choking

(in MU)

System

Condition

& Grid fail

(in MU)

Flood

passing &

Any Other

Reasons

(in MU)

Total

(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%


275

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

6.11.7 Inferences


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


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.












276


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

FY2014-15

FY2015-16

















277



months is expected to be as given in the table below:


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.


Plant Availability (%) 75% 80% 80% 80%

Documents

UJVNL Business Plan - UERCuerc.gov.in/ordersPetitions/Petitions/2013-14/MYT Petitions and... · Business Plan of UJVN Limited for Control Period 2 TABLE OF CONTENTS 1 INTRODUCTION