Business Plan for UJVNL - UJVN Limited Dehradun...

Business Plan of UJVN Limited for Control Period 

Business Plan for the Control Period 

(April 1, 2013 to March 31, 2016) 

BEFORE THE 

HON’BLE UTTARAKHAND ELECTRICITY REGULATORY COMMISSION 

DEHRADUN, UTTARAKHAND 

UJVN Limited 

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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 19 th 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 

20


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 

19 Tapovan 0.80 2005 ROR Dak 

Gadera 

143.50 1.07 

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 

21


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 

22


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. 

23


Table 4: Planned Capacity Addition by UJVN Limited 

S.No. 

Name of 

Estimated 

District 

River/ 

Expected 

Project 

Potential 

Tributary 

Commissioning 

(MW) 

Year 

1 Vyasi 120 Dehradun Yamuna 2016 

2 Lakhwar 300 Dehradun Yamuna 2018 

3 Bowla 

Nandprayag 

300 Chamoli Alaknanda 2019 

4 Tamak lata 250 Chamoli Dhauliganga 2019 

5 Nand Pyayag 

Langasu 

6 Sirkari Bhyol 

Rupsiabagar 

100 Chamoli Alaknanda 2020 

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 

24


control period. Two hydro projects namely Pala Maneri and Bhairon Ghati on the 

Bhagirathi River are currently on hold due to environmental issues. Taluka Sankri, 

Rishiganga – I , Rishigana – II and Sela Urthing are still under planning phase and 

hence no capital expenditure will be incurred during the control period. Sela Urthing 

is expected to be commissioned in 2023 and no capital expenditure is expected to be 

incurred during the control period. 

In addition to these Large Hydroelectric Projects, quite a number of Small 

Hydroelectric Projects are in operation as well as in various stages of implementation 

requiring substantial capital investments during the Control Period 2013-14 to 

2015-16. These have been appended as Annexure-15. 

Effort towards Diversification of Generation Base 

1.4.3 Electricity demand in the state has grown exponentially due to rapid industrialization 

as a result of industry friendly policies and special package granted to the State by 

the Union Government. The demand for electricity has been growing at the rate of 

about 14% per annum during the last 8 years and the demand-supply gap is 

increasing. At present power generation in the state is wholly dependent on 

Hydro projects and allocation of power from central pool is not sufficient to meet 

the requirement of the State. The power deficit becomes acute during winter season 

as freezing temperatures causes low river discharges leading to lower generation 

whereas demand goes up significantly. 

Bottlenecks in development of Hydro projects 

1.4.4 The state could not harness the full potential of Hydro power due to various reasons, 

notably among them are the inordinate delay in various clearances for the upcoming 

hydro projects, suspension / closure of 480 MW Pala Maneri & 381 MW 

Bhairoghati projects of State PSU (UJVN Limited), 600 MW Lohari Nag Pala project of 

25


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. 

26


1.4.7 In this reference a meeting was held on 11 th 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 10 th 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 

27


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. 

28


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 

29


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. 

30


2 CAPITAL EXPENDITURE PLAN – 

UPCOMING PROJECTS 

31


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 1 st 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: 

32


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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Capital 

Expenditure 104.00 100.00 200.00 200.00 332.23 936.23 

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

33


Table 6: Capital Cost – Vyasi Project 

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

ABSTRACT OF COST (February 2010) 

S. No Description Amount (Rs. in 

Crores) 

A CIVIL WORKS 

1 DIRECT CHARGES 

I - Works 

A - Preliminary 28.36 

B - Land 32.52 

C - Works 317.79 

J - Power Plant Civil Works 172.57 

K - Buildings 19.66 

M - Plantation 1.00 

O - Miscellaneous 16.61 

P - Maintenance During Construction 5.44 

Q - Special Tools and Plants 1.27 

R - Communication 34.06 

X - Environment and Ecology 23.34 

Y - Losses on Stock 1.36 

TOTAL OF I - WORKS 653.97 

II - Establishment 49.72 

III - Tools and Plants 1.00 

IV - Suspense - 

V- Receipt & Recoveries -0.94 

TOTAL DIRECT CHARGES 703.74 

2 INDIRECT CHARGES 

I - Capitalised Value of Abatement of Land Revenue 0.36 

II - Audit & Accounts Charges 3.27 

TOTAL INDIRECT CHARGES 3.63 

TOTAL CIVIL WORKS 707.38 

B ELECTRICAL WORKS 149.79 

TOTAL COST (CIVIL + ELECTRICAL) 857.17 

INTEREST DURING CONSTRUCTION 72.51 

FINANCING CHARGES 6.55 

TOTAL COST INCLUDING IDC & FINANCING CHARGES 936.23 

Total 936.23 

34


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. 

35


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: 

Year 

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

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

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% 

36


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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Year 

Capital 

Expenditure 104.00 100.00 200.00 200.00 332.23 936.23 

Capitalization - - - - 936.23 936.23 

37


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 3 rd 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 3 rd 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 

38


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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Capital Expenditure 

(Power Component) 242.00 80.00 200.00 250.00 818.23 1,590.23 


(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 : 

39


Table 10: Capital Cost – Lakhwar Project 

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

ABSTRACT OF COST (February 2010) 


Crores) 

A CIVIL WORKS 


I - Works 


B - Land 142.92 

C - Works 2,423.90 



M - Plantation - 







TOTAL OF I - WORKS 3,194.31 





TOTAL DIRECT CHARGES 3,538.83 





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 

40




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 3 rd 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 16 th July, 2010. 

41


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: 

42


Year 

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

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

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 

43


2.3 Kishau Multipurpose Project (660 MW) 


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 : 

44


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

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 


(Power Component) - - 10.00 100.00 4,399.00 4,509.00 


(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 : 

45


Table 14: Capital Cost – Kishau Project 

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

ABSTRACT OF COST (June 2010) 


Crores) 

A CIVIL WORKS 


I - Works 


B - Land 800.40 

C - Works 4,184.60 
























46



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 15 th 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 

47


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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Year 

Capital 

Expenditure - - 10.00 100.00 4,399.00 4,509.00 


48


2.4 Sirkari Bhyol Rupsiabagar Hydroelectric Project (210 MW) 


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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Capital 

Expenditure - - - 5.00 888.63 893.63 


49


Table 18: Capital Cost – Sirkari Bhyol Rupsiabagar Project 

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

ABSTRACT OF COST (June 2003) 


Crores) 

A CIVIL WORKS 


I - Works 


B - Land 1.80 

C - Works 276.50 









Y - Losses on Stock -1.16 




IV - Suspense 5.14 









TOTAL COST (CIVIL + ELECTRICAL) 752.56 


FINANCING CHARGES - 

TOTAL COST INCLUDING IDC & FINANCING CHARGES 893.63 

Total 893.63 

50





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). 




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. 

51



table below: 

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

Year 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

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 

Capital 

Expenditure - - - 5.00 888.63 893.63 


52


2.5 Bowala Nand Prayag Hydroelectric Project (300 MW) 


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 



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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Capital 

Expenditure - 5.00 100.00 200.00 2,702.24 3,007.24 


53


Table 22: Capital Cost – Bowala Nand Prayag Project 

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

ABSTRACT OF COST (May 2012) 


Crores) 

A CIVIL WORKS 


I - Works 


B - Land 34.67 

C - Works 763.52 
























FINANCING CHARGES 290.35 

TOTAL COST INCLUDING IDC & FINANCING CHARGES 3,007.24 

Total 3,007.24 

54



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 18 th July 2007. Most of the chapters of the DPR have 

been cleared by CEA/ CWC. Revised final DPR prepared in 6 volumes has been 

55


submitted to CEA in 22 sets for Techno Economic Concurrence on 18 th 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 tiedup 

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: 

56


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 - 


Equity - JV 

Partner 0.00% 22.20% 22.20% 22.20% 22.20% 22.20% 


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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Year 

Capital 

Expenditure - 5.00 100.00 200.00 2,702.24 3,007.24 


57


2.6 Nand Prayag Langasu Hydroelectric Project (100 MW) 


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 



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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Capital 

Expenditure - - 5.00 100.00 1,296.19 1,401.19 


58


Table 26: Capital Cost – Nand Prayag Langasu Project 

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

ABSTRACT OF COST August 2010) 


Crores) 

A CIVIL WORKS 


I - Works 


B - Land 3.45 

C - Works 228.28 
























FINANCING CHARGES - 

TOTAL COST INCLUDING IDC & FINANCING CHARGES 1,401.19 

Total 1,401.19 

59





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 5 th 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. 

60


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 - 


Equity - JV 

Partner - - 1.11 22.20 287.75 311.06 

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

Equity - 


Equity - JV 

Partner 0.00% 0.00% 22.20% 22.20% 22.20% 22.20% 

61



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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Year 

Capital 

Expenditure - - 5.00 100.00 1,296.19 1,401.19 


62


2.7 Tamak Lata Hydroelectric Project (250 MW) 


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% 



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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Capital 

Expenditure - - 2.00 50.00 1,001.45 1,053.45 


63


Table 30: Capital Cost – Tamak Lata Project 

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

ABSTRACT OF COST (November 2007) 


Crores) 

A CIVIL WORKS 


I - Works 


B - Land 19.83 

C - Works 198.85 









Y - Losses on Stock - 





V- Receipt & Recoveries - 



I - Capitalised Value of Abatement of Land Revenue - 







64


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 

65


budgetary support of GoU envisaged for UJVN Limited while debt is yet to be tiedup 

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 - 


Equity - JV 

Partner - - 0.44 11.10 222.32 233.87 

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

Equity - 


Equity - JV 

Partner 0.00% 0.00% 22.20% 22.20% 22.20% 22.20% 


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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Year 

Capital 

Expenditure - - 2.00 50.00 1,001.45 1,053.45 


66


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. Technoeconomic 

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. 

67


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 

9 Present status of work 

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, Hydromechanical 

equipment design chapters etc. have 

been cleared. For concurrence on Geology, civil 

design and foundation engineering additional Geotechnical 

investigation are required. 

The project is discontinued by Government of India 

on the basis of meeting of National Ganga River 

Basin Authority (NGRBA) held on dated 01.11.2010 

as communicated by GoU vide letter no. 

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. 

68


3 CAPITAL EXPENDITURE PLAN – 

EXISTING PROJECTS 

69


3.1 Chibro Power Station (240 MW) 


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 5 th 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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Capital 

Expenditure - - - 27.73 157.15 184.88 

70


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 : 

71


Table 34: Capital Cost – Chibro Project 

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

ABSTRACT OF COST 


Crores) 


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 - 





R - Communication - 

S - Power Plant 

S1 - Mechanical Equipment 49.63 

S2 - Electrical Equipment 77.79 













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 

72


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. 

73




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 56 th 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 

74


Year 

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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

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 1 st November 2015 31 st March 2017 

Unit II 1 st June 2017 31 st March 2018 

Unit III 1 st June 2018 31 st March 2019 

Unit IV 1 st June 2019 31 st 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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Year 

Capital 

Expenditure - - - 27.73 157.15 184.88 


75


3.2 Khodri Power Station (120 MW) 


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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Capital 

Expenditure - - - 25.44 144.19 169.63 

76





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

provided in the table on the next page : 

77


Table 38: Capital Cost – Khodri Project 

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



Crores) 


I - Works 


B - Land - 

C - Works - 

C1 - Civil Works - 

C2 - Hydrulic Steel Structures - 



























IDC 2.51 




Total 169.63 

78


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% 




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





79








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 

80


Year 

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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Year 

Capital 

Expenditure - - - 25.44 144.19 169.63 


81


3.3 Dhakrani Power Station (33.75 MW) 


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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Capital 

Expenditure - - 17.46 23.28 75.67 116.41 


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 

82


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 : 

83


Table 42: Capital Cost – Dhakrani Project 

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



Crores) 


I - Works 


B - Land - 

C - Works 





























IDC 2.34 




Total 116.41 

84


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% 




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





85



Report. 












The DPR has been approved by Board of UJVN Limited in its 56 th 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. 




86




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 

Year 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

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 1 st October 2014 30 th June 2015 

Unit II 1 st October 2015 30 th June 2016 

Unit III 1 st October 2016 30 th 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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Year 

Capital 

Expenditure - - 17.46 23.28 75.67 116.41 

Capitalization - - - 38.80 77.61 116.41 

87


3.4 Dhalipur Power Station (51 MW) 


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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Capital 

Expenditure - - 17.52 23.36 75.93 116.81 


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


Annexure-12. UJVNL Limited had carried out a study through Uttarakhand 

88







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 : 

89


Table 46: Capital Cost – Dhalipur Project 

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



Crores) 


I - Works 


B - Land - 

C - Works - 





























IDC 2.20 




Total 116.81 

90



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




benefits; 


benefits; 





RESULTS 

Site Dhalipur Power 

Station 


EIRR (%) 24.96% 




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





91


The detailed working of the economic analysis is provided in 


the Detailed 













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. 




92






Table 47: Funding Pattern during Control Period – Dhalipur Project 

Year 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

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 1 st October 2014 30 th 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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Year 

Capital 

Expenditure - - 17.52 23.36 75.93 116.81 


93


3.5 Kulhal Power Station (30 MW) 


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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Capital 

Expenditure - - 17.81 23.74 77.17 118.72 


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


Annexure-12. UJVNL Limited had carried out a study through 

Uttarakhand 

94







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 : 

95


Table 50: Capital Cost – Kulhal Project 

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



Crores) 


I - Works 


B - Land - 

C - Works - 





























IDC 2.38 




Total 118.72 

96



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




benefits; 


benefits; 





RESULTS 

Site Kulhal Power 

Station 


EIRR (%) 20.57% 




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





97
















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 30 th June 

2013.. 






98




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

Year 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

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 1 st October 2014 30 th 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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Year 

Capital 

Expenditure - - 17.81 23.74 77.17 118.72 


99


3.6 Tiloth Power Station (90 MW) 


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 : 

100


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

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Capital 

Expenditure - 18.93 25.25 44.18 37.87 126.23 




DPR) subject to same water discharge. 


Details of the total project cost are 

101


Table 54: Capital Cost – Tiloth Project 

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



Crores) 


I - Works 


B - Land - 

C - Works 





























IDC 2.53 




Total 126.23 

102


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% 




the Tiloth Power Station represents an economically feasible project. The 

conclusion is drawn due to the following observations: 




103
















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. 






104


Year 

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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

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 

upto 

31.03.2013 

FY 2013- 

14 

FY 2014- 

15 

FY 2015- 

16 

Rs.Crores 

after 

31.03.2016 Total 

Year 

Capital 

Expenditure - 18.93 25.25 44.18 37.87 126.23 

Capitalization - - 42.08 42.08 42.08 126.23 

105


3.7 Chilla Power Station (144 MW) 


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 

Capital Expenditure - - 33.70 128.06 175.24 337.00 



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 

106


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 : 

107


Table 58: Capital Cost – Chilla Project 

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



Crores) 


I - Works 

A - Preliminary - 

B - Land - 

C - Works 








O - Miscellaneous - 

P - Maintenance During Construction - 






X - Environment and Ecology - 

Y - Losses on Stock - 


II - Establishment 

III - Tools and Plants 






II - Audit & Accounts Charges - 

TOTAL INDIRECT CHARGES - 


Escalation till start of M&U Measure 

IDC 37.00 

Commitment Fees - 


Guarantee Fees - 

Total 337.00 

108


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% 



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: 




109





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: 

110


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 


Capital Expenditure - - 33.70 128.06 175.24 337.00 


111


3.8 Khatima Power Station (41.40 MW) 


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 



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

112


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


113


Table 62: Capital Cost – Khatima Project 

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



Crores) 


I - Works 


B - Land - 

C - Works 










Q - Special Tools and Plants - 



S1 - Mechanical Equipment 

S2 - Electrical Equipment 

X - Environment and Ecology 

129.50 

- 













Escalation till start of M&U Measure - 

IDC 35.14 




Total 220.44 

114


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% 



115


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

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





The detailed working of the economic analysis is provided in 


the Detailed 




DPR for RM&U of Khatima Power Station has been approved by the BoD of 

UJVN Limited in its 56 th 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 1 st October 2012 


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


116



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 1 st October 2012 31 st March 2014 

Unit II 1 st April 2014 31 st January 2015 

Unit III 1 st January 2015 31 st 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 

117


3.9 Ramganga Power Station (198 MW) 


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 : 

118


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

Rs. Crores 


Capital Expenditure - 39.01 81.44 119.80 214.97 455.22 




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 : 

119


Table 66: Capital Cost – Ramganga Project 

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



Crores) 


I - Works 


B - Land - 

C - Works 









P - Maintenance During Construction - 

Q - Special Tools and Plants - 





X - Environment and Ecology - 













Escalation till start of M&U Measure - 

IDC 94.38 




Total 455.22 

120


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% 




the Ramganga Power Station represents an economically feasible project. The 

conclusion is drawn due to the following observations: 




121







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 13 th 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% 

122



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

under: 


Unit I 15 th June 2014 28 th February 2015 

Unit II 15 th June 2015 28 th February 2016 

Unit III 15 th June 2016 28 th 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 


Capital Expenditure - 39.01 81.44 119.80 214.97 455.22 

Capitalization - - 151.74 151.74 151.74 455.22 

123


3.10 Maneri Bhali - II Hydroelectric Project (304 MW) 


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. 

124



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: 

125


Table 70: Capital Cost – Maneri Bhali - II Project 

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



Crores) 

1 Rehabilitation 15.56 

2 Compensation for the affected people 1.14 

3 Construction of Protection wall 32.32 

4 Modification of tail race channel 24.15 

5 Construction of Office Building at Joshiyara 1.03 

6 Construciton of Joshiyara colony 1.10 

7 Construciton of Road from Joshiyara Bridge to Flushing 

2.22 

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

Right Bank (0.4 km) 

8 Balance infrastructure works for affected villages of 

9.50 

Joshiyara, Gyanshu & Kansain as per their demands 

9 Construction of boundary wall, sectrity fencing and gate for 

1.21 

Shaktipuram colony and Shifting of existing boundary wall 

of Shaktipuram colony and provide the separate way for 

villagers behind Shaktipuram colony 

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

1.10 

V Residence in Shaktipuram colony, Chinyalisaur 

11 Construction of school building for Saraswati Shishu Mandir 

2.00 

School in Shaktipuram Colony Chinyalisaur 

12 Strengthening of water distribution system of Shaktipuram 

0.89 

colony, Chinyalisaur 

13 Construction of workshop building at Dharasu power house 

1.69 

of MB-II project 

14 Protection work on hill slope behind power house 2.57 

15 Testing of surge shaft gate 5.00 

16 Centage Charges 60.84 

17 Payment to M/sNPCC against claim of Principal Agreement 

12.68 

in accordance to the decision of High Power Committee 

18 Liabilities against major civil contract of MB-II Project 

a. Reimbursement of Sales Tax 8.15 

b. Reimbursement of royalty 0.45 

c. Award given by the arbitrator in favour of M/s Hydel 

30.73 

Construction (P) Ltd against dispute related to swellex rock 

bolt, Steel fivre as extra items and loss due to flood along 

with the interest of Rs. 95424/- per day 

d. Payment against misc. works 0.26 

e. Security 0.35 

f. Pending Liability of GSI 0.95 

g. Expenditure incurred for arbitration 0.35 

Total 216.23 



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

126


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 

127


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 30 th 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 

128


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. 

129


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 

130


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. 

131


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 hydromechanical 

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 

132


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. 

133


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 runof-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 

134


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. 

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3.15 Refurbishment of Maneri Dam at Maneri, Uttrakashi 

3.15.1 Maneri Dam is situated across river Bhagirathi at Maneri, 15 Km towards Gangotri 

from district Uttarkashi. It is a 39 m high concrete gravity dam with 4 nos. ogee 

spillways having crest elevation at 1280.5 m, each 13 m wide, separated by 4 m wide 

piers and followed by a roller bucket at an elevation of 1261 m. 

3.15.2 The power intake consists of 4 bays with sill beam level at the elevation of 1283.25 

m and is located on left bank of river and designed for a maximum discharge of 99 

cumecs. Out of this discharge 70 cumec is carried out through 8.86 Km long head 

race tunnel for power generation at Tiloth Power House (90 MW) & rest is 

discharged through flushing tunnel. The capacity of the dam reservoir is 0.6 million 

cubic meters. 

3.15.3 Maneri Bhali Stage-I (3 x 30 MW) was commissioned in the year 1984 and it was 

constructed by UP Irrigation Department and financed by UPSEB. Since then 

Operation & Maintenance was carried out by Irrigation Department but since 

19.10.08, the Operation & Maintenance of Maneri Dam has been taken over from 

Irrigation department by UJVN Ltd. 

3.15.4 During its life, the Maneri Dam has faced several floods including the disastrous 

flood in August 1978 and due to this flood the reservoir got silted fully up to crest 

and since then, the total sediment load carried by the river has been passing through 

the spillway. Further, due to heavy floods in August and September, 2010, the sill 

beam of gates and other associated structures have got damaged severely. 

3.15.5 There is an acute bend just upstream of dam spillway structure with a reverse acute 

bend about 50 m downstream of spillway structure. In addition to this a protruding 

rock cliff exists on the left bank downstream of spillway/dam axis. The above 

topographical features combined with floods induce the asymmetrical flow of water 

136


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. 

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3.16 Special Closure Works of Civil & Hydro Mechanical Structures for 

Yamuna Hydel Scheme Stage–I (Part-I&II) & Stage-IV 

3.16.1 Yamuna Hydroelectric Scheme Stage-I at Dakpathar,46 Kms from Dehradun was 

launched in 1960 and completed in 1965. Under this scheme the barrage has been 

constructed across the river Yamuna at Dakpathar for diverting the discharge of 

Yamuna River through a Power Channel of 198 cumes capacity for power generation 

through two nos. Power Houses of 33.75 MW and 51 MW capacities located at 

Dhakrani and Dhalipur respectively. 

3.16.2 Under Yamuna Hydel Scheme Stage-IV, Kulhal Power Station constructed during the 

period 1970-75, the tail race discharge of Dhalipur Power House along with 

discharge of Asan River was picked up by another barrage constructed across river 

Asan just downstream of Dhalipur Power House and further the water was carried 

through a 4 Km long power channel to utilize it for power generation at Kulhal Power 

House with installed capacity of 30 MW. Since commissioning of the project the 

channel was operated and maintained by Irrigation Department. From the midnight 

of 30/4/2010 it has been taken over by UJVN Limited and since then it is being 

operated and maintained by UJVN Ltd. 

3.16.3 Closure for special repair of submerged parts of Dakpathar and Asan Barrages, 

Power channel and hydro mechanical components is necessary as the above said 

projects run throughout the year without any interruption except in high flood 

condition. As such, the routine maintenance of submerged parts of structures cannot 

be carried out and a lot of wear & tear of very serious nature in civil structures as 

well as hydro-mechanical equipment takes place every year. To inspect & maintain 

such parts, regular closures have not been taken since the commissioning of this 

project. Last closure was allowed for Dakpathar Barrage & Asan Barrage in Jan, 2005 

and Feb, 2005. Since then submerged structure/ parts could not be repaired. Lining 

of power channel is severely damaged and bed of the channel needs to be repaired. 

138


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. 

139


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 

140


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 & 

Sr. 

No. 

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) 

Name of Work Amount FY14 FY15 Sources 

1 Refurbishment of Asan Barrage, at 

Dhalipur (Dehradun) 

2 Refurbishing of Ichari Dam, at Ichari, Koti 

(Dehradun) 

3 Rehabilitation Work of Virbhadra 

Barrage, Pashulok, Rishikesh. 

4 Refurbishment of Dakpathar Barrage, at 

Dakpathar (Dehradun) 

5 Refurbishment of Maneri Dam at Maneri, 

Uttrakashi 

6 Special Closure Works of Civil & Hydro 

Mechanical Structures for Yamuna Hydel 

Scheme Stage–I (Part-I&II) & Stage-IV. 

7 Closure of Chilla HEP for Special Repair of 

Power Channel, Submerged Parts Of 

Structures & Hydro-Mechanical 

Components of Virbhadra Barrage, 

Pashulok, Rishikesh. 

535.32 214.13 321.19 Grant 

under 

2237.57 895.03 1342.54 DRIP 

Scheme 

625.81 250.32 375.49 

672.21 268.88 403.33 

453.24 181.30 271.94 

1673.15 

645.00 

1673.15 

645.00 

Debt 

Equity 

ratio of 

70:30 

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 

141


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. 

142


4 MAJOR SHUTDOWN PLAN OF POWER 

STATIONS 

143


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 

144


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 

145


5 SUMMARY 

146


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 

147


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 

148


6 TECHNICAL REPORT OF EXISTING 

POWER STATIONS 

149


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 

150


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 

151


available / relevant ”and (ii) the maximum generation possible from the Tiloth 

Power Station considering that there were no machine and other outages. Due to 

non-availability of 90% dependable 10 daily inflows pattern as approved in the DPR 

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

available past reliable 10 daily discharge data. 

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

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

for the period April 2000 to March 2012 and the same has been considered 

for determination of 90% dependable year and Design Energy (Data is 

provided in the Annexure 1). Reliable data for periods prior to April 2000 is 

not available with UJVN Limited. On considering the average daily discharge 

of the year for the same period, the 90% dependable year is found to be 

2008-09, as given in the table below: 

Table 77: 90% dependable year – Tiloth Power Station 

Sl. No. 

10 Daily 

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% 

For calculation of power following formula has been used: 

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

152


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: 

153


Table 78: Discharge & Generation Data – Tiloth Power Station 

Sr.no. Month Net Discharge Net Head Power Potential Energy (kWh) 

(cumecs) (meter) (kW) 

1 April-I 27.7 147.5 35,803.3 85,92,800.2 

2 April-II 39.1 147.5 50,427.1 1,21,02,500.6 

3 April-III 53.0 147.5 68,384.9 1,64,12,381.6 

4 May-I 49.9 147.5 64,406.5 1,54,57,557.2 

5 May-II 63.9 147.5 82,534.8 1,98,08,346.0 

6 May-III 68.6 147.5 88,634.7 2,25,72,000.0 

7 June-I 62.2 147.5 80,375.8 1,92,90,181.0 

8 June-II 37.5 147.5 48,479.8 1,16,35,160.3 

9 June-III 33.2 147.5 42,848.6 1,02,83,654.5 

10 July-I 38.5 147.5 49,706.6 1,19,29,572.3 

11 July-II 15.2 147.5 19,641.7 47,14,000.2 

12 July-III 5.4 147.5 6,929.5 18,29,382.9 

13 Aug-I - 147.5 - - 

14 Aug-II - 147.5 - - 

15 Aug-III - 147.5 - - 

16 Sept-I 6.2 147.5 7,996.9 19,19,256.0 

17 Sept-III 41.9 147.5 54,062.0 1,29,74,889.7 

18 Sept-III 61.4 147.5 79,329.8 1,90,39,156.1 

19 Oct-I 69.0 147.5 89,073.8 2,05,20,000.0 

20 Oct-II 64.1 147.5 82,793.0 1,98,70,327.5 

21 Oct-III 54.5 147.5 70,338.4 1,85,69,336.6 

22 Nov-I 48.1 147.5 62,168.7 1,49,20,487.8 

23 Nov-II 44.0 147.5 56,821.5 1,36,37,161.6 

24 Nov-III 41.0 147.5 52,911.5 1,26,98,762.2 

25 Dec-I 37.4 147.5 48,283.6 1,15,88,054.4 

26 Dec-II 34.7 147.5 44,829.4 1,07,59,052.3 

27 Dec-III 31.9 147.5 41,156.6 1,08,65,350.6 

28 Jan-I 29.5 147.5 38,095.4 91,42,885.7 

29 Jan-II 27.8 147.5 35,835.6 86,00,547.9 

30 Jan-III 26.8 147.5 34,541.8 91,19,022.8 

31 Feb-I 26.1 147.5 33,710.2 80,90,440.4 

32 Feb-II 24.7 147.5 31,928.2 76,62,768.3 

33 Feb-III 24.5 147.5 31,607.3 60,68,605.1 

34 March-I 24.8 147.5 32,075.4 76,98,097.8 

35 March-II 25.0 147.5 32,236.8 77,36,836.2 

36 March-III 25.4 147.5 32,800.9 86,59,430.3 

Annual Energy Generation 

39,47,68,006.1 

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Table 79: Design Energy: Tiloth Power Station 

Sr. No Particulars Unit Value 

1 Generation Lost due to uncontrollable situation % 6.1% 

2 Generation loss due to uncontrollable situation kWh 24156595.35 

3 Design Energy kWh 370611410.70 

4 Design Energy MUs 370.61 

5 Availability of FY 08-09 % 72% 

While determining Design Energy, a 6.1% (based on losses experienced 

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

generation has been considered. This reduction has been considered to take 

into account generation loss experienced due to uncontrollable factors such 

as forced stoppages of machines and outages to prevent damage to the 

machines due to heavy silting during flash floods, flood passing and grid 

failure etc. These losses represent Hydrological risk and other uncontrollable 

risks which UJVN Limited cannot control in spite of its robust operating 

procedures. This figure of 6.1% has been determined considering generation 

loss on account of uncontrollable factors as a percentage of maximum 

possible generation without any unit and other outages for the period 2000- 

12 for which data is available with UJVN Limited. The details of these losses 

are provided in the table below. 

Table 80: Uncontrollable Losses – Tiloth Power Station 

Sr. No % losses B/D of 

Equipment 

(1) 

1 

2 

Flushing & 

Choking 

(2) 

System 

Condition 

(3) 

Flood 

Passing & 

Any Other 

Reason (4) 

Total (5) 

Gross losses as % of Max. 

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

Losses due to uncontrollable 

factors (5)-(1) 6.1% 

(ii) On the basis of Maximum possible plant generation 

In view of the limited data size, UJVN Limited has also considered an alternate 

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

and generation lost on account of various operational & hydrological reasons 

155


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: 

156


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

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 

On re-arranging the data in the descending order and considering the 90% 

dependable year, the Design Energy for the Tiloth Power Station is computed 

to be 394.05 MUs as given in the table below: 

Table 82: Design Energy – Tiloth Power Station 

Sr. No. Particular Unit Value 

1 Dependable Year FY 2008-09 

2 Maximum Possible Generation MUs 419.74 

3 Plant Availability for FY 2008-09 % 72% 

4 Energy losses due to uncontrollable factors % 6.1% 

5 Energy losses due to uncontrollable factors MUs 25.68 

6 Design Energy (2)-(5) MUs 394.05 

6.2.3 Determination of NAPAF 

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

below: 

157


Sr. No (1) 

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

Month (2) 

Total 

Running 

Hrs. of all 

the units 

(Hrs.) (3) 

Reserve 

Outage 

(Hrs.) (4) 

Forced 

Outage 

(Hrs.) (5) 

Planned Maintenance 

Annual 

Mainten 

ance 

(Hrs.) (6) 

Capital 

Major 

repairs (Hrs.) 

(7) 

Total 

hours(max) 

(Hrs.) (8) 

Plant 

Availability 

% (9) 

(Col. 3+Col. 

4)/Col.8 

1 April 16795 5775 967 2376 7 25920 87% 

2 May 25084 983 705 12 0 26784 97% 

3 June 23757 1013 962 134 54 25920 96% 

4 July 10435 5421 1589 9339 0 26784 59% 

5 August 1728 828 221 24007 0 26784 10% 

6 Sept 18697 663 291 6268 0 25919 75% 

7 Oct 24506 1864 152 262 0 26784 98% 

8 Nov 16877 6231 44 2768 0 25920 89% 

9 Dec 13096 5496 690 7502 0 26784 69% 

10 Jan 10887 7892 789 6471 744 26783 70% 

11 Feb 9536 6442 5 8425 0 24408 65% 

12 March 11876 5591 22 9295 0 26784 65% 

Total 183274 48199 6437 76859 805 315574 73% 

6.2.3.2 The Tiloth Power Station experiences excessive forced shut downs during the 

monsoon period. The reasons for these forced shut downs have been provided in 

the section below. The average plant availability during the last 12 years is around 

73%. The plant availability is showing sign of improvement and during the last five 

years it has improved over the last 12 years’ average. 

6.2.4 Special Circumstances and Abnormal Operating Conditions 

6.2.4.1 Since its commissioning, Tiloth Power Station operates on base load during 

monsoon period and as a peaking station during non-monsoon period when 

discharge in the river reduces and Power Station has to be run on partial load. But 

due to silting of Maneri Dam, the peaking capacity has also reduced and the Power 

Station meets evening and morning peaks at partial load during the lean discharge 

period. 

6.2.4.2 Study of the available inflow data revealed that the maximum capacity can be 

generated between May to September (excluding the heavy monsoon period 

158


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. 

159


6.2.5 Plant Outages and Breakdowns 

6.2.5.1 Apart from above facts, when flood recedes lot of silt having substantial quartzite 

particles are lodged in cavities and caves on both banks of river which gets 

dislodged when level of river starts rising as a result of snow melting during 

summer season and is carried to the machines through water conductor system 

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

beyond the control of UJVN Limited 

6.2.5.2 The forced outage data for the period 2000-12 has revealed that 25% of the total 

energy loss is on this account. The table below provides the details. 

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

Sr. No. Month↓ B/D of 

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% 

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 

160


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 

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 

8 

Total 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% 

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 

161


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 hydromechanical 

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 

162


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: 

163


FY2013-14 

Unit No. Start Date End date Days Reasons 

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

Interim repair of spherical 

15-07-2013 31-07-2013 17 

2 

valve of Unit 2 

15-01-2014 31-01-2014 17 Interim repair of Unit-2 

01-02-2014 15-02-2014 15 Interim repair of of Unit 3 

3 

FY2014-15 

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) 


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

Major repair of Unit 2 

15-07-2014 30-08-2014 47 

2 

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

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

Interim repair of Unit 3, 

3 

15-07-2014 31-07-2014 17 Interim repair of 

spherical valve of Unit 3 

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

3 

Interim repair of Unit 3, 

15-07-2015 31-07-2015 17 Interim repair of 


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 %. 

164


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. 

165


6.3 TECHNICAL REPORT OF CHIBRO POWER STATION 


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 

166


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 

167





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. 



168


Table 87: Discharge & Generation Data – Chibro Power Station 

Sl.no. Month Net Discharge Net Head Power Potential 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 


611364477 

169


Table 88: Design Energy- Chibro Power Station 

Sr. no Particulars Units Value 

1 Generation Loss due to uncontrollable situation % 4.15% 

2 Energy loss during monsoon and forced outages kWh 2,53,67,508.8 

3 Design Energy kWh 58,59,96,968.1 

4 Design Energy (MU) MU 586.0 

5 Plant Availability of FY 04-05 % 77.9 


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 


Equipment 

(1) 

1 

2 

Flushing & 

Choking 

(2) 

System 

Condition 

(3) 

Flood 

Passing & 

Any Other 

Reason (4) 

Total (5) 

Gross lossesas a % of Max 

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

Losses due to Uncontrollable 

factor (5)-(1) 4.15% 




170




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 

Sr. no. 

Actual Gross 

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 

171



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

computed to be 628.18 MUs. 

Table 91: Design Energy – Chibro Power Station 




3 Plant Availability for FY 04-05 % 77.92 





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

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

Sr. No (1) Month (2) 

Total 

Running 

Hrs. of all 

the units 

(Hrs.) (3) 

Reserve 

Outage 

(Hrs.) (4) 

Forced 

Outage 

(Hrs.) (5) 


Annual 

Mainten 

ance 

(Hrs.) (6) 

Capital 

Major 


(7) 

Total hours 

(max) 

(Hrs.) (8) 


Availability 

% (9) 

(Col. 3+Col. 

4)/Col.8 

1 April 13569 9460 475 10336 720 34560 67% 

2 May 18596 9259 237 7353 267 35712 78% 

3 June 20203 8808 1081 4312 156 34560 84% 

4 July 25925 6513 1266 1957 51 35712 91% 

5 August 27615 4465 1537 2086 9 35712 90% 

6 Sept 25706 7509 199 1146 0 34560 96% 

7 Oct 17182 13396 580 4158 396 35712 86% 

8 Nov 10594 13597 703 8956 710 34560 70% 

9 Dec 8558 13465 779 12166 744 35712 62% 

10 Jan 7897 12872 1401 13127 415 35712 58% 

11 Feb 7777 11105 75 12891 696 32544 58% 

12 March 11739 11605 65 11681 622 35712 65% 

Total 195361 122054 8398 90169 4786 420768 75% 

6.3.3.2 The Chibro plant experiences excessive forced shut downs during the monsoon 

seasons. The reasons for these forced shut downs have been provided in the 

section below. The average plant availability during the last 12 years is around 

75%. 

172



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. 



173


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


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 









8 

Total Aux. and Transformation losses as % of 


% 1.53% 

174



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. 


& 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% 



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. 

175


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 





176


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. 


6.3.11.1 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 




177



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. 

178


6.4 TECHNICAL REPORT OF DHAKRANI POWER STATION 


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 nonavailability 

of 90% dependable 10 daily inflows pattern as approved in the DPR of 

179


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 

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 




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

180


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. 



181


Table 96: Discharge & Generation Data – Dhakrani Power Station 



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 


13,21,36,896.3 

182


Table 97- Design Energy: Dhakrani Power Station 



2 Energy loss during monsoon and forced outages kWh 9633453.9 


4 Design Energy (MU) MUs 122.5 



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 


Equipment 

(1) 

1 

2 

Flushing 

& 

Choking 

(2) 

System 

Condition 

(3) 

Flood 

Passing & 

Any Other 

Reason (4) 

Total (5) 

Gross losses as % of Max 



factors (5)-(1) 7.3% 

(ii) On the basis of Maximum Possible Plant generation 



183




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 

Sr. no. 

Actual Gross 

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 

184


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 


Total 

Running 

Hrs. of all 

the units 

(Hrs.) (3) 

Reserve 

Outage 

(Hrs.) (4) 

Forced 

Outage 

(Hrs.) (5) 


Annual 

Mainten 

ance 

(Hrs.) (6) 

Capital 

Major 


(7) 

Total hours 

(max) 

(Hrs.) (8) 


Availability 

% (9) 

(Col. 3+Col. 

4)/Col.8 

1 April 13168 7727 64 4961 0 25920 81% 

2 May 16875 7223 194 2492 0 26784 90% 

3 June 18275 6630 55 960 0 25920 96% 

4 July 22734 3230 76 744 0 26784 97% 

5 August 23481 2489 64 750 0 26784 97% 

6 Sept 22895 2788 237 0 0 25920 99% 

7 Oct 18275 8375 134 0 0 26784 99% 

8 Nov 11308 8703 253 5656 0 25920 77% 

9 Dec 9564 8704 21 8495 0 26784 68% 

10 Jan 8997 9049 626 8112 0 26784 67% 

11 Feb 7561 8197 17 8633 0 24408 65% 

12 March 10520 6512 167 9585 0 26784 64% 

Total 183653 79627 1908 50388 0 315576 83% 

6.4.3.2 The plant availability for this period is around 83%. The Dhakrani Power Station 

experiences excessive forced shut downs during the monsoon period. The reasons 

for these forced shut downs have been provided in the section below. 

185



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. 

186


Table 102: % Generation Loss on account of various Factors – Dhakrani 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 0.74 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% 



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. 

187


Table 103: Auxiliary and Transformation Losses – Dhakrani Power Station 


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% 



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 




188


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. 

189



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. 


6.4.10.1 The annual maintenance schedule and the RMU schedule proposed for Dhakrani 


FY2013-14 





FY2014-15 

190



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. 

191


6.5 TECHNICAL REPORT OF DHALIPUR POWER STATION 


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 

192


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 

193









generator and turbine of Dhalipur Power Station UJVN Limited for the 



much lower than the designed values. 



194


Table 105: Discharge & Generation Data – Dhalipur Power Station 



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 


20,07,20,545.5 

195


Table 106: Design Energy- Dhalipur Power Station 

Sr. No Parameter Unit Value 







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 


Equipment 

(1) 

1 

2 

Flushing & 

Choking 

(2) 

System 

Condition 

(3) 

Flood 

Passing & 

Any Other 

Reason (4) 

Total (5) 




factors (5)-(1) 5.01% 




196



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 

Sr. no. 

Actual Gross 

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 

197



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 


Total 

Running 

Hrs. of all 

the units 

(Hrs.) (3) 

Reserve 

Outage 

(Hrs.) (4) 

Forced 

Outage 

(Hrs.) (5) 


Annual 

Mainten 

ance 

(Hrs.) (6) 

Capital 

Major 


(7) 

Total hours 

(max) 

(Hrs.) (8) 


Availability 

% (9) 

(Col. 3+Col. 

4)/Col.8 

1 April 11732 5848 974 3766 1440 23760 74% 

2 May 15652 6258 475 1662 505 24552 89% 

3 June 16997 6050 457 256 0 23760 97% 

4 July 21716 2779 57 0 0 24552 100% 

5 August 20935 2111 1499 7 0 24552 94% 

6 Sept 20561 2342 857 0 0 23760 96% 

7 Oct 16888 7346 318 0 0 24552 99% 

8 Nov 10383 8372 0 5005 0 23760 79% 

9 Dec 8758 6758 222 8814 0 24552 63% 

10 Jan 8389 8552 13 6854 744 24552 69% 

11 Feb 6994 6472 139 8115 672 22392 60% 

12 March 9490 5957 615 7746 744 24552 63% 

Total 168495 68845 5626 42225 4105 289296 82% 

6.5.3.2 The Dhalipur Power Station experiences forced shut downs during the monsoon 

period. The reasons for these forced shut downs have been provided in the 

section below. The average plant availability during the last 11 year is around 

82%. 

198



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. 




199


Table 111: % Generation Loss on account of various Factors – Dhalipur 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 0.62 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% 



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 


200


Table 112: Auxiliary and Transformation Losses – Dhalipur Power Station 







1 Total Gross Generation 1998-12) MUs 3089.55 







8 



% 1.94% 


& 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% 

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 


201








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 

202


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. 


6.5.10.1 The annual maintenance schedule and the RMU schedule proposed for Dhalipur 


FY2013-14 





203


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. 

204


6.6 TECHNICAL REPORT OF KHODRI POWER STATION 


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 


205


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: 

206


Table 113: 90% Dependable year – Khodri Power Station 

Sl. No. 



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: 

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 

207


Table 114: Discharge & Generation Data – Power Station 



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 


32,22,18,833.7 

208


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) 

1 

2 

Flushing & 

Choking 

(2) 

System 

Condition 

(3) 

Flood 

Passing & 

Any Other 

Reason (4) 

Total (5) 




factors (5)-(1) 3.42% 




209


and generation lost on account of various operational & Hydrological reasons 

for which the data is available since 1999-2012. The loss of generation 

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

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

Flood passing and other reasons. UJVN Limited computes on a daily basis, the 

generation opportunity missed by it on account of these reasons. Thus the 

maximum energy that Khodri Power Station possibly could have generated 

(with 100% Unit availability and with no generation loss on account of any 

reason) is the gross generation by its Units and the generation loss suffered 

by it. This is an equally good approach for an existing plant for computing 

Design Energy when compared with the method of computing Design Energy 

on the basis of river discharge data as it is based on existing unit efficiencies 

instead of their design values, considers the impact of other project design 

related issues and also operational restrictions imposed on the plant. The 

maximum possible year wise generation has been computed in the table 

below: 

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

Sr. no. 

Actual Gross 

Generation 

(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 

210



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 


Total 

Running 

Hrs. of all 

the units 

(Hrs.) (3) 

Reserve 

Outage 

(Hrs.) (4) 

Forced 

Outage 

(Hrs.) (5) 


Annual 

Mainten 

ance 

(Hrs.) (6) 

Capital 

Major 


(7) 

Total hours 

(max) 

(Hrs.) (8) 


Availability 

% (9) 

(Col. 3+Col. 

4)/Col.8 

1 April 13552 14275 207 3004 3522 34560 81% 

2 May 18647 14024 135 1399 1507 35712 91% 

3 June 20183 13381 137 859 0 34560 97% 

4 July 25795 9312 395 210 0 35712 98% 

5 August 27675 7794 106 137 0 35712 99% 

6 Sept 25619 8814 90 37 0 34560 100% 

7 Oct 17247 14647 355 993 2470 35712 89% 

8 Nov 10591 15404 70 2889 5606 34560 75% 

9 Dec 8569 15635 71 3841 7596 35712 68% 

10 Jan 8057 16406 906 3290 7053 35712 69% 

11 Feb 7603 14498 427 4059 5957 32544 68% 

12 March 11640 14782 59 3025 6206 35712 74% 

Total 195178 158972 2958 23743 39917 420768 84% 

6.6.3.2 The Khodri Power Station experiences forced shut downs during the monsoon 

period. The reasons for these forced shut downs have been provided in the section 

below. The average plant availability during last 12 years is around 84%. 

211



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 



212


Table 120: % Generation Loss on account of various Factors – Khodri 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 0.74 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 



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. 

213


Table 121: Auxiliary and Transformation Losses – Khodri Power Station 













8 



% 0.7% 



& 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% 

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 


214








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. 


215


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. 


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


2013-14 






2014-15 

216







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: 








217


6.7 TECHNICAL REPORT OF KULHAL POWER STATION 


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 

218


Energy data, moderated by past experience where available /relevant” and (ii) the 

maximum generation possible from the Kulhal Power Station considering that there 

were no machine and other outages. Due to non-availability of 90% dependable 10 

daily inflows pattern as approved in the DPR of the project, Design Energy and 

NAPAF have been calculated on the basis of available past reliable 10 daily 

discharge data. 

(i) 

On the basis of Average of 10 daily discharges 

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

for the period April 2001 to March 2012 and the same has been considered 

for determination of 90% dependable year and Design Energy (this data is 

provided in the annexure 6). Reliable data for periods prior to April 2001 is 

not available with UJVN Limited. On considering the average daily discharge 

data of the years for the same period, the 90% dependable year is found to 

be 2001-02, as given in the table below: 

Table 122: 90% dependable year – Kulhal Power Station 

Sl. No. 

10 Daily 

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 



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 

219


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. 



220


Table 123: Discharge & Generation Data – Kulhal Power Station 

Sr.no. Month Net Discharge 

(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 


13,09,53,860.0 

221


Table 124: Design Energy-Kulhal Power Station 



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

3 Design Energy kWh 12,39,44,219.1 














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

Table 125: Uncontrollable Losses – Kulhal Power Station 


Equipment 

(1) 

1 

2 

Flushing & 

Choking 

(2) 

System 

Condition 

(3) 

Flood 

Passing & 

Any Other 

Reason (4) 

Total (5) 




factors (5)-(1) 5.35% 



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

and generation lost on account of various operational & Hydrological reasons 

222


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 

Sr. no. 

Actual Gross 

Generation 

(MU) 

Generation 

Loss (MU) 

Maximum 

Possible 

Generation 

(MU) 


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


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 

223


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: 

Sr. No (1) 

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

Month (2) 

Total 

Running 

Hrs. of all 

the units 

(Hrs.) (3) 

Reserve 

Outage 

(Hrs.) (4) 

Forced 

Outage 

(Hrs.) (5) 


Annual 

Mainten 

ance 

(Hrs.) (6) 

Capital 

Major 


(7) 

Total hours 

(max) 

(Hrs.) (8) 


Availability 

% (9) 

(Col. 3+Col. 

4)/Col.8 

1 April 13604 8524 615 1017 0 23760 93% 

2 May 16689 7773 90 0 0 24552 100% 

3 June 17445 5993 322 0 0 23760 99% 

4 July 21867 2149 536 0 0 24552 98% 

5 August 22400 2068 84 0 0 24552 100% 

6 Sept 21734 2012 9 5 0 23760 100% 

7 Oct 18780 5513 130 129 0 24552 99% 

8 Nov 13044 6013 0 4703 0 23760 80% 

9 Dec 10360 7023 605 6564 0 24552 71% 

10 Jan 9616 7831 518 6587 0 24552 71% 

11 Feb 7872 8291 626 5603 0 22392 72% 

12 March 11734 5401 763 6654 0 24552 70% 

Total 185145 68591 4298 31262 0 289296 88% 

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


6.7.4.1 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 

224


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 


225



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 












8 



% 3.1% 


& 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% 

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. 

226


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. 

227




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 


228


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: 








229


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

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

230


6.8 TECHNICAL REPORT OF CHILLA POWER STATION 


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 

231


were no machine and other outages. Due to non-availability of 90% dependable 10 

daily inflows pattern as approved in the DPR of the project, Design energy and 

NAPAF have been calculated on the basis of available past reliable 10 daily 

discharge data. 

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

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

only for the period April 2002 to March 2012 and the same has been 

considered for determination of Design Energy (this data is provided in the 

annexure 7). Reliable data for periods prior to April 2002 is not available with 

UJVN limited. On considering the yearly average daily discharge of the same 

period, the 90% dependable year is found to be 2005-06, as given in the table 

below: 

Table 131: 90% dependable year – Chilla Power Station 

Sr. No. 

10 Daily 

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 





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



232


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


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



233


Table 132: Discharge & Generation Data – Chilla Power Station 



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 


82,49,13,291.7 

234


Table 133: Design Energy: Chilla Power Station 






5 Plant Availability of 05-06 % 76.4 






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 


Equipment 

(1) 

1 

2 

Flushing & 

Choking 

(2) 


System 

Condition 

(3) 

Flood 

Passing & 

Any Other 

Reason (4) 

Total (5) 




factors (5)-(1) 5.6% 





235






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 

Sr. no. 

Actual Gross 

Generation 

(MU) 

Generation 

Loss (MU) 

Maximum 

Possible 

Generation 

(MU) 


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

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

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 

236


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 

Sr. No (1) 

137 below: 

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

Month (2) 

Total 

Running 

Hrs. of all 

the units 

(Hrs.) (3) 

Reserve 

Outage 

(Hrs.) (4) 

Forced 

Outage 

(Hrs.) (5) 


Annual 

Mainten 

ance 

(Hrs.) (6) 

Capital 

Major 


(7) 

Total hours 

(max) 

(Hrs.) (8) 


Availability 

% (9) 

(Col. 3+Col. 

4)/Col.8 

1 April 16904 2223 1210 8463 0 28800 66% 

2 May 21091 1605 1205 5859 0 29760 76% 

3 June 23244 1476 1029 3051 0 28800 86% 

4 July 25973 1195 1725 867 0 29760 91% 

5 August 26135 1622 1205 798 0 29760 93% 

6 Sept 24879 1294 1288 1339 0 28800 91% 

7 Oct 25670 1428 133 2433 0 29760 91% 

8 Nov 19489 2325 1547 5535 0 28800 76% 

9 Dec 17261 3817 287 8395 0 29760 71% 

10 Jan 15731 4018 46 9965 0 29760 66% 

11 Feb 14502 3523 397 8746 0 27168 66% 

12 March 16476 2766 402 10116 0 29760 65% 

Total 247355 27292 10474 65567 0 350688 78% 

6.8.3.2 The average plant availability during the last 10 years is around 78%. The Chilla 

Power Station experiences forced shut downs during the monsoon seasons. The 

reasons for these forced shut downs have been provided in the section below. 

237



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. 





238




becomes beyond the control of UJVN Limited 



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




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. 

239


Table 139: Auxiliary and Transformation Losses – Chilla Power Station 









8 



% 1.0% 

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 



& 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% 



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. 

240


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. 


241


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. 


6.8.10.1 The annual maintenance schedule and the RMU schedule proposed for Chilla 


2013-14 






242


2014-15 


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




2015-16 


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
















243


6.9 TECHNICAL REPORT OF KHATIMA POWER STATION 


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. 

244


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 nonavailability 

of 90% dependable 10 daily inflows pattern as approved in the DPR of 

245


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 

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 





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 


246



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 



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 


24,51,54,254.1 

247


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 


Equipment 

(1) 

1 

2 

Flushing & 

Choking 

(2) 


System 

Condition 

(3) 

Flood 

Passing & 

Any Other 

Reason (4) 

Total (5) 




factors (5)-(1) 4.7% 


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



248




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 

Sr. no. 

Actual Gross 

Generation 

(MU) 

Generation 

Loss (MU) 


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; 

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 

249



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 

Sr. No (1) 

Month (2) 

Total 

Running 

Hrs. of all 

the units 

(Hrs.) (3) 

Reserve 

Outage 

(Hrs.) (4) 

Forced 

Outage 

(Hrs.) (5) 


Annual 

Mainten 

ance 

(Hrs.) (6) 

Capital 

Major 


(7) 

Total hours 

(max) 

(Hrs.) (8) 


Availability 

% (9) 

(Col. 3+Col. 

4)/Col.8 

1 April 14810 2777 1431 6902 0 25920 68% 

2 May 17705 2634 3247 3198 0 26784 76% 

3 June 19192 1706 3132 1890 0 25920 81% 

4 July 22471 1248 2564 501 0 26784 89% 

5 August 23437 1274 1766 307 0 26784 92% 

6 Sept 22841 1470 1341 268 0 25920 94% 

7 Oct 21129 4465 829 361 0 26784 96% 

8 Nov 15813 4109 1090 4908 0 25920 77% 

9 Dec 16216 2789 111 7668 0 26784 71% 

10 Jan 14568 3419 526 8271 0 26784 67% 

11 Feb 11975 3579 1102 7752 0 24408 64% 

12 March 13327 4695 1222 7540 0 26784 67% 

Total 213484 34165 18361 49566 0 315576 78% 

6.9.3.2 The average plant availability for the period 2000-12 is around 78%.The Khatima 

plant experiences forced shut downs during the monsoon seasons. The reasons for 

these forced shut downs have been provided in the section below. 

6.9.4 


6.9.5.1 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 

250


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 


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 


6.9.7 


251



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 









8 



% 0.8% 



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 


252








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 

253


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. 


6.9.12.1 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 

254




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. 

255


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:- 

256


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 bypassing 

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 

257


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 

Minimum Tail Water Level 

Maximum Head (Theoretical) 

366.200 m 

256.100 m 

110.100 m 

Minimum Net Head 

Minimum Head Water Level 

332.900 m 

258


Maximum Tail Water Level 

Minimum Head (Theoretical) 

278.000 m 

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. 

259


Sr. No Year Full 

Reservoir 

Level(FRL) 

Table 149: Annual Discharge 

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 

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. 

260


Sr. No. 

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. 

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 

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: 

261


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

basis 



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 

262


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: 

263


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: 

264


Table 152: Plant availability based on Peaking Capability 

Sr. no. Month Average three 

hour Peaking 

Capacity 

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 nonavailability 

of units as regular and other maintenance requirements are scheduled 

during season (monsoon) when plant is not in operation. 

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 

Weighted average of 

13 peaking capability 

39 77 

14 Forced Outage 2% 1.5% 

Expected Average 

15 peaking Capability 

38 76 

16 Installed Capacity 198 

17 NAPAF 19% 38% 

265


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. 

Sr. no. Year Availability (%) 

1 2007-08 75.66 

2 2008-09 80.24 

3 2009-10 85.12 

4 2010-11 92.98 

5 2011-12 89.26 

6 Average 84.65 

6.10.9 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. 

266


Table 154: Auxiliary and Transformation losses 

Sr. no. Year Gross 

Generation 

(MU) 

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. 

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 

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 



267


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 

268


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. 


6.10.14.1 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 



269


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. 

270


6.11 TECHNICAL REPORT OF MANERI BHALI – II HYDROELECTRIC PROJECT 


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 

271


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 

Sr. No (1) 

Month (2) 

Total 

Running 

Hrs. of all 

the units 

(Hrs.) (3) 

Reserve 

Outage 

(Hrs.) (4) 

Forced 

Outage 

(Hrs.) (5) 


Annual 

Mainten 

ance 

(Hrs.) (6) 

Capital 

Major 


(7) 

Total hours 

(max) 

(Hrs.) (8) 


Availability 

% (9) 

(Col. 3+Col. 

4)/Col.8 

1 April 4998 2291 925 3306 0 11520 63% 

2 May 9031 1673 122 754 326 11904 90% 

3 June 10084 838 598 0 0 11520 95% 

4 July 9611 1148 1086 60 0 11904 90% 

5 August 6650 3452 942 860 0 11904 85% 

6 Sept 9106 1352 346 716 0 11520 91% 

7 Oct 8459 2470 323 653 0 11904 92% 

8 Nov 5431 3482 122 2486 0 11520 77% 

9 Dec 4188 2572 300 4845 0 11904 57% 

10 Jan 3385 2991 0 5529 0 11904 54% 

11 Feb 2836 2882 74 5057 0 10848 53% 

12 March 3684 2690 1664 3866 0 11904 54% 

Total 77460 27838 6501 28131 326 140256 75% 

6.11.3.2 The average plant availability of Maneri Bhali Stage-II HEP during last four years is 

around 75%.The Maneri Bhali Stage II Hydro Electric Project experiences forced 

272


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. 

273




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

Hydroelectric Project 


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% 



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. 

274


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









8 



% 0.66% 



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. 

275



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. 


6.11.9.1 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 






276




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


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


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. 

277


7 ANNEXURES 

278


7.1 Annexure 1: 10 Daily Discharge Tiloth Power Station 

Sr. No Month 

10 Daily 

Average 00-01 2001-02 2002-03 2003-04 2004-05 2005-06 2006-07 2007-08 2008-09 2009-10 2010-11 2011-12 

1 April 1 24.825 29.28 48.06 42.35 31.42 41.36 36.49 46.66 27.73 26.41 33.45 31.33 

2 2 41.82 5.66 62.06 59.77 37.43 51.10 38.16 62.18 39.05 30.68 48.93 40.00 

3 3 52.09 10.08 68.60 64.06 42.10 65.61 54.56 62.09 52.96 39.47 48.60 54.25 

4 May 1 67.98 46.37 70.80 69.32 40.36 67.25 66.47 68.66 49.88 49.63 61.46 69.10 

5 2 70.32 55.80 69.25 70.11 64.47 65.18 70.65 66.46 63.92 54.23 60.38 69.31 

6 3 67.94 68.60 70.11 70.96 70.93 68.52 69.32 69.36 68.64 66.55 65.39 67.30 

7 June 1 53.33 69.30 70.71 66.21 71.01 68.36 70.60 59.91 62.25 67.98 66.52 70.47 

8 2 54.63 65.85 65.08 64.37 69.15 68.98 71.02 66.866 37.544 67.59 67.79 68.413 

9 3 50.89 68.42 58.29 66.38 67.31 67.59 69.68 67.11 33.18 53.58 66.19 59.61 

10 July 1 52.13 6.07 18.55 52.28 53.77 24.56 46.09 30.72 38.49 63.88 57.42 68.86 

11 2 0.00 0.00 0.00 26.36 8.33 0.00 23.29 43.69 15.21 59.93 47.86 59.90 

12 3 0.00 0.00 0.00 0.00 22.68 2.01 1.52 13.77 5.37 47.53 27.88 56.88 

13 Aug 1 0.00 0.00 0.00 0.00 0.00 0.00 46.09 30.72 0.00 12.67 9.82 40.28 

14 2 0.00 0.00 0.00 0.00 0.00 0.00 23.29 43.69 0.00 0.00 0.00 33.30 

15 3 0.00 0.00 0.00 12.13 2.21 0.00 1.52 13.77182 0 2.170909 0.771818 41.19 

16 Sept 1 19.52 21.33 10.58 62.43 43.34 29.81 58.93 11.42 6.19 24.97 45.17 38.37 

17 2 63.18 49.68 37.51 64.55 56.91 60.64 68.36 67.29 41.87 60.85 47.03 44.18 

18 3 68.90 47.39 67.48 64.95 70.04 67.69 65.85 70.22 61.44 66.69 64.31 47.41 

19 Oct 1 67.58 60.86 69.49 68.41 69.49 67.70 68.34 65.83 68.98 66.68 67.25 51.39 

20 2 57.55 57.99 69.27 67.88 63.22 67.58 62.71 59.85 64.12 55.89 68.69 67.84 

21 3 51.84 51.76 61.53 57.55 52.09 56.93 48.07 50.07 54.47 45.66 67.97 59.66 

22 Nov 1 48.75 42.88 52.57 51.08 45.24 46.90 42.10 44.97 48.15 41.66 60.40 51.29 

23 2 38.08 36.19 45.44 45.28 41.68 42.05 38.81 39.77 44.00 39.24 53.09 46.12 

24 3 31.48 32.25 42.19 39.42 37.64 37.81 35.59 38.35 40.98 33.69 47.77 42.56 

25 Dec 1 30.74 30.26 37.55 36.87 34.42 33.93 34.35 34.44 37.39 31.68 43.56 38.69 

26 2 28.24 29.93 36.36 34.73 32.01 34.63 32.26 31.55 34.72 29.97 38.68 34.91 

27 3 24.72 27.48 32.33 31.31 30.11 31.84 29.72 30.21 31.87 27.42 35.55 31.74 

28 Jan 1 23.11 25.69 29.48 29.24 29.39 30.39 27.17 28.78 29.50 26.12 33.69 30.53 

29 2 22.66 25.19 26.69 27.34 27.22 30.50 25.89 29.02 27.75 23.90 31.24 29.60 

30 3 23.45 23.48 26.26 27.55 27.15 29.38 24.43 27.37 26.75 22.67 29.84 25.06 

31 Feb 1 23.79 24.48 26.90 25.83 25.48 29.02 23.80 25.89 26.11 22.27 28.77 26.77 

32 2 23.88 25.56 24.99 26.09 27.71 29.27 24.91 25.93 24.73 23.69 29.74 25.94 

33 3 23.81 25.79 28.69 26.54 26.98 28.85 24.10 27.65 24.48 25.52 27.50 26.09 

34 March 1 21.26 30.80 28.97 26.30 30.87 26.74 24.96 31.45 24.84 24.55 27.40 27.95 

35 2 22.20 37.83 29.39 31.25 39.78 30.17 30.55 31.86 24.97 28.12 30.91 23.66 

36 3 25.65 42.13 40.54 29.48 37.99 29.92 40.21 29.53 25.40 39.00 35.51 29.98 

Average 35.37 32.62 39.54 42.39 39.69 39.60 42.10 42.67 35.05 38.97 43.76 44.58 

279


7.2 Annexure 2: 10 Daily Discharge Chibro Power Station 

Sl.no. Month 

10 Daily 93-94 94-95 95-96 96-97 97-98 98-99 99-00 00-01 01-02 02-03 03-04 04-05 05-06 06-07 07-08 08-09 09-10 10-11 11-12 12-13 

Average 

1 April i 80.70 58.90 78.60 90.20 57.40 156.70 53.56 87.10 41.10 99.90 69.10 45.10 83.10 54.80 99.30 60.30 35.50 39.10 49.90 71.60 

2 ii 99.60 58.10 93.40 118.80 72.70 132.30 60.30 90.70 51.00 106.10 87.40 48.90 82.80 60.20 104.10 67.60 40.40 51.70 66.70 61.20 

3 iii 121.70 59.90 109.10 121.20 81.00 147.40 77.10 97.50 57.20 131.90 97.30 53.00 101.00 68.00 81.20 77.30 47.90 47.60 81.50 66.20 

4 May i 162.50 100.50 108.30 117.20 99.10 148.30 70.80 110.30 73.80 154.30 85.60 60.00 98.00 96.40 91.60 83.30 49.00 61.90 99.30 65.10 

5 ii 97.60 97.90 179.40 99.20 81.20 143.80 69.20 147.30 98.60 181.00 104.90 77.10 94.70 118.60 94.20 81.80 61.90 51.70 108.70 86.10 

6 iii 143.09 151.09 118.27 111.00 81.91 169.00 96.45 130.55 83.82 138.45 109.09 74.36 86.73 115.36 78.91 103.00 67.36 77.27 123.82 105.09 

7 June i 119.80 140.10 179.90 137.90 86.50 152.50 62.10 99.80 94.00 120.50 154.80 58.00 85.80 97.70 83.60 113.30 71.80 79.90 103.10 104.10 

8 ii 145.50 132.20 165.50 157.60 114.60 156.90 94.20 135.80 136.30 126.90 128.30 84.20 111.40 68.50 121.20 152.00 45.20 69.90 116.10 100.00 

9 iii 139.70 172.90 124.20 191.10 160.90 172.90 118.90 121.30 143.70 140.60 134.40 67.00 171.60 95.90 111.80 185.80 83.20 96.20 164.40 116.80 

10 July i 132.80 193.80 152.30 175.30 183.80 182.00 113.40 156.30 169.00 145.40 142.20 90.80 119.90 141.10 137.40 170.30 79.10 136.00 163.60 134.33 

11 ii 72.60 189.60 184.80 189.70 197.60 171.00 145.50 137.33 161.80 136.40 187.50 78.00 120.60 151.00 119.90 205.60 145.30 155.80 186.90 

12 iii 184.64 127.45 171.82 168.55 196.36 177.45 189.27 106.27 191.73 114.82 205.91 94.27 136.36 166.36 153.36 196.91 139.73 169.36 180.55 

13 Aug i 198.20 177.20 149.20 200.50 170.40 190.20 208.50 155.50 172.30 161.10 154.10 148.60 167.20 165.90 127.80 178.80 114.10 179.50 178.40 

14 ii 183.70 181.00 210.60 182.30 198.20 194.56 215.20 181.90 161.00 164.20 159.50 167.10 170.20 197.40 171.50 138.30 139.50 165.30 122.00 

15 iii 140.09 181.00 206.64 183.36 212.18 188.45 206.18 167.73 180.09 183.27 128.00 155.45 180.27 189.64 181.27 193.18 94.82 120.91 156.82 

16 Sept i 193.60 183.40 141.80 167.70 220.60 205.30 163.30 177.30 142.20 200.50 189.20 125.70 154.80 168.40 181.10 164.60 117.30 166.50 185.30 

17 ii 205.10 223.20 209.20 213.70 185.00 203.80 188.70 140.10 106.60 206.78 209.90 103.70 159.90 123.40 127.70 108.40 141.00 143.50 208.40 

18 iii 174.90 173.70 193.80 182.00 101.90 192.60 174.50 116.00 82.50 172.10 176.80 76.70 189.10 92.70 107.50 180.50 123.10 105.00 156.40 

19 Oct i 114.70 123.50 137.10 139.50 85.70 194.10 112.70 92.90 71.80 112.90 106.80 63.30 142.90 72.50 81.20 148.30 94.60 190.20 115.60 

20 ii 89.60 96.40 108.40 102.80 86.10 133.11 81.80 74.80 57.60 93.40 90.50 83.30 102.80 60.90 65.10 115.30 68.10 146.50 98.70 

21 iii 70.82 77.27 84.82 85.64 79.27 210.00 71.45 65.91 52.73 75.00 75.55 54.09 79.18 58.64 61.00 91.55 52.91 126.91 80.55 

22 Nov i 63.50 67.40 71.60 70.80 69.80 147.60 62.80 60.70 49.90 63.70 63.60 43.10 62.20 51.00 52.30 76.00 50.00 95.90 69.30 

23 ii 57.30 60.50 62.00 63.30 73.70 112.10 51.90 54.00 43.50 55.60 58.20 36.50 55.70 46.90 46.70 65.80 51.90 80.60 62.10 

24 iii 49.50 53.70 55.90 57.10 64.70 90.30 49.70 48.00 42.80 50.90 51.10 35.60 49.70 44.60 43.40 58.20 43.10 70.50 55.10 

25 Dec i 45.60 50.30 52.20 49.90 66.70 77.80 46.10 44.30 37.10 44.70 46.20 39.00 44.70 42.40 41.60 51.60 39.80 62.20 50.20 

26 ii 41.90 45.50 48.30 45.20 89.10 66.30 42.10 40.70 38.10 42.10 47.20 36.40 40.20 40.90 42.30 48.00 35.70 55.20 46.00 

27 iii 37.36 45.18 45.82 44.73 67.91 59.73 39.18 37.36 36.82 39.00 40.00 34.73 38.73 32.64 37.36 46.18 33.91 55.82 41.73 

28 Jan i 35.80 43.30 41.80 40.20 57.70 57.50 37.10 37.60 33.00 36.70 37.10 35.70 41.80 31.70 38.30 42.10 33.10 55.60 43.20 

29 ii 42.60 45.80 55.00 41.00 53.60 51.30 41.50 34.60 33.50 34.00 35.50 33.70 47.60 31.00 45.70 40.20 31.60 50.10 46.90 

30 iii 36.36 40.18 49.64 40.36 47.18 55.55 36.09 33.09 33.73 35.09 49.45 37.09 41.36 27.91 39.09 36.27 28.55 46.18 40.18 

31 Feb i 38.00 37.60 45.20 38.30 43.80 51.60 48.90 31.20 38.10 35.90 45.30 45.90 41.40 27.00 40.80 33.30 32.70 45.90 40.80 

32 ii 40.40 75.60 51.20 40.90 46.60 52.30 61.70 31.78 57.40 47.60 44.50 66.70 40.30 40.50 42.50 37.50 34.30 52.60 41.10 

33 iii 68.25 53.00 75.11 37.88 77.00 52.88 45.00 30.13 49.25 55.63 44.22 60.88 38.38 35.63 45.44 31.75 34.00 46.50 44.78 

34 March i 51.60 55.20 71.40 38.30 103.20 50.10 49.40 26.50 109.20 71.20 42.90 77.90 35.10 58.80 55.90 30.10 33.40 49.40 49.30 

35 ii 59.40 51.10 90.20 38.63 111.60 46.90 53.30 26.60 99.40 53.10 49.30 102.50 50.60 118.20 57.60 28.00 34.20 54.80 48.30 

36 iii 58.50 101.45 112.18 39.27 118.27 44.18 72.64 39.82 99.36 67.45 45.91 99.91 48.27 111.18 51.55 33.73 45.18 59.00 62.36 

Month Average 100.13 103.75 112.19 106.70 107.07 129.08 92.38 88.26 87.34 102.52 97.22 72.25 92.27 86.76 85.16 96.95 66.10 90.88 97.05 

280


7.3 Annexure 3: 10 Daily Discharge Dhakrani Power Station 

Sl.no. 

10 day 94-95 95-96 96-97 97-98 98-99 99-00 00-01 01-02 02-03 03-04 04-05 05-06 06-07 07-08 08-09 09-10 10-11 11-12 12-13 

Month average 

1 April i 87.13 89.83 111.10 85.88 184.86 65.31 106.16 51.33 116.41 84.67 56.80 104.25 69.65 120.96 65.06 45.83 43.61 61.64 81.25 

2 ii 67.23 109.24 128.60 92.18 165.77 69.89 105.75 59.65 138.01 108.00 58.96 105.58 75.31 129.69 76.53 49.74 59.07 85.13 67.17 

3 iii 70.71 125.69 146.10 101.03 182.39 87.44 112.33 70.19 156.30 122.50 63.89 121.82 82.24 104.80 88.01 54.43 55.79 98.25 75.66 

4 May i 115.43 129.87 137.90 109.74 177.17 82.53 131.70 89.29 172.22 106.94 71.43 119.77 117.39 114.54 91.50 57.43 71.96 117.86 70.31 

5 ii 115.21 191.77 115.10 120.25 164.90 77.35 172.94 113.59 189.98 125.48 84.43 114.91 140.78 116.47 91.25 69.78 56.53 128.95 95.07 

6 iii 173.71 127.38 125.45 123.31 196.46 108.75 160.42 101.21 151.35 132.19 82.80 104.73 137.31 91.27 116.31 71.49 84.24 140.35 114.21 

7 June i 156.48 188.63 154.70 120.50 163.50 71.80 106.89 110.42 137.05 176.61 69.34 101.97 112.77 92.19 128.87 78.36 90.30 125.11 112.03 

8 ii 142.49 172.46 191.60 131.30 171.13 112.94 164.07 144.26 149.03 150.38 103.44 126.77 78.52 133.73 168.59 52.98 79.97 146.24 106.90 

9 iii 187.16 138.04 191.40 177.90 197.91 123.20 144.24 164.69 160.93 150.85 82.54 184.62 106.23 129.15 195.32 85.72 111.12 182.08 129.90 

10 July i 173.62 175.53 174.60 183.60 179.21 116.55 158.56 185.04 172.72 164.07 130.81 137.20 159.02 162.77 175.75 83.75 146.24 183.88 

11 ii 168.24 146.49 189.50 187.60 172.58 151.91 135.11 176.48 168.36 179.52 119.19 126.87 169.92 176.21 170.97 145.77 161.64 176.42 

12 iii 133.87 151.62 194.18 172.73 190.22 164.08 156.06 182.07 162.70 180.25 117.61 162.95 170.90 175.57 188.82 157.43 171.51 178.39 

13 Aug i 151.13 142.85 194.20 148.40 179.73 175.48 186.68 157.52 179.52 150.03 182.93 175.78 178.88 152.00 174.54 134.23 173.79 175.21 

14 ii 150.51 186.39 163.80 156.40 148.21 162.02 185.67 164.90 165.34 176.85 188.00 187.28 192.63 173.33 130.90 161.87 228.80 122.63 

15 iii 185.56 191.66 175.36 159.09 181.22 188.73 195.02 188.66 191.68 178.86 190.91 196.60 195.23 184.33 192.58 116.85 142.90 144.84 

16 Sept i 188.08 122.90 166.60 184.70 196.28 188.87 195.42 185.64 189.92 179.76 177.62 195.46 193.33 182.68 193.77 131.41 155.73 182.75 

17 ii 197.77 195.10 196.70 196.00 197.80 191.76 169.09 150.76 173.19 192.51 175.36 151.81 163.53 171.22 141.39 146.44 121.58 192.93 

18 iii 183.26 189.40 192.60 170.90 178.45 188.86 155.28 122.17 196.13 193.57 133.70 193.97 135.09 137.96 177.31 156.19 91.92 189.06 

19 Oct i 151.36 160.50 162.40 142.80 181.97 152.48 125.55 108.97 169.50 173.54 113.62 193.54 110.27 99.35 163.01 110.10 182.51 156.44 

20 ii 119.07 138.10 134.50 101.70 107.69 108.64 98.99 87.30 137.99 131.59 136.43 149.61 87.82 82.95 135.30 75.24 177.25 140.14 

21 iii 93.12 107.91 112.09 98.82 192.48 97.51 88.79 75.31 103.56 102.85 98.42 122.68 72.71 83.10 117.68 59.51 166.33 111.79 

22 Nov i 75.50 87.20 86.20 95.00 172.35 83.29 77.42 68.59 85.67 86.81 77.23 95.35 65.45 67.98 95.07 62.72 134.82 94.66 

23 ii 67.54 77.90 70.90 95.90 144.47 70.70 64.18 58.70 75.35 74.65 65.31 79.98 56.00 63.06 82.41 65.42 115.27 84.81 

24 iii 58.40 68.10 67.20 85.10 218.27 63.74 60.26 58.28 70.01 64.71 58.16 72.64 53.35 57.56 75.73 51.86 99.39 76.10 

25 Dec i 52.74 62.80 60.90 108.70 106.61 61.15 55.24 51.26 61.20 65.52 57.00 63.52 51.25 52.37 67.99 44.05 86.91 70.16 

26 ii 50.31 58.60 57.70 116.40 90.36 57.89 51.97 90.54 55.80 63.96 52.58 59.82 47.93 53.73 61.41 40.47 76.60 65.28 

27 iii 51.29 55.45 57.55 89.00 77.47 50.61 45.93 86.42 52.29 57.64 48.12 53.56 41.43 46.38 55.81 37.18 75.76 55.64 

28 Jan i 49.72 51.10 53.16 77.20 75.55 48.80 47.32 42.03 50.71 49.41 48.77 56.69 38.56 45.98 47.55 38.58 78.69 57.04 

29 ii 53.29 70.00 51.86 72.70 67.97 58.91 42.89 40.24 47.82 49.18 14.18 65.05 35.92 50.82 45.81 36.09 68.65 62.14 

30 iii 47.87 60.55 48.81 63.09 72.43 61.35 40.05 40.07 48.67 72.79 0.00 56.32 32.96 43.80 47.28 33.18 58.56 50.81 

31 Feb i 43.95 38.40 47.21 56.80 65.12 66.29 37.24 50.35 50.91 66.03 0.00 52.46 33.28 48.24 46.43 41.19 56.94 49.02 

32 ii 86.78 0.00 53.25 59.50 62.40 85.54 36.43 77.27 78.15 56.38 0.00 51.02 52.38 49.10 52.42 39.78 69.01 49.11 

33 iii 53.32 0.00 44.98 115.88 63.54 61.20 39.59 1.00 74.68 0.00 0.00 48.56 45.92 51.31 47.66 41.30 66.74 53.90 

34 March i 57.06 76.80 59.48 155.00 57.36 60.92 36.17 0.00 106.15 33.37 36.32 45.45 76.70 63.39 44.00 38.81 65.49 58.08 

35 ii 51.53 97.20 71.53 174.20 52.77 66.19 36.48 0.00 70.50 61.32 128.29 65.14 139.80 66.14 39.95 41.83 68.85 55.78 

36 iii 110.58 130.55 86.51 165.64 53.65 92.23 52.75 107.18 85.35 59.21 121.97 61.18 133.92 51.17 44.21 53.24 73.36 74.47 

Month Average 108.92 114.33 118.77 124.86 141.40 102.08 104.96 96.15 122.09 111.72 87.39 111.25 101.51 100.70 106.59 75.28 104.66 111.03 

281


7.4 Annexure 4: 10 Daily Discharge Dhalipur Power Station 

Sl.no. Month 10 daily 94-95 95-96 96-97 97-98 98-99 99-00 00-01 01-02 02-03 03-04 04-05 05-06 06-07 07-08 08-09 09-10 10-11 11-12 

average 

1 April i 87.13 89.83 111.10 85.88 184.86 65.31 106.16 51.33 116.41 84.67 56.80 104.25 69.65 120.96 65.06 45.83 43.61 61.64 

2 ii 67.23 109.24 128.60 92.18 165.77 69.89 105.75 59.65 138.01 108.00 58.96 105.58 75.31 129.69 76.53 49.74 59.07 85.13 

3 iii 70.71 125.69 146.10 101.03 182.39 87.44 112.33 70.19 156.30 122.50 63.89 121.82 82.24 104.80 88.01 54.43 55.79 98.25 

4 May i 115.43 129.87 137.90 109.74 177.17 82.53 131.70 89.29 172.22 106.94 71.43 119.77 117.39 114.54 91.50 57.43 71.96 117.86 

5 ii 115.21 191.77 115.10 120.25 164.90 77.35 172.94 113.59 189.98 125.48 84.43 114.91 140.78 116.47 91.25 69.78 56.53 128.95 

6 iii 173.71 127.38 125.45 123.31 196.46 108.75 160.42 101.21 151.35 132.19 82.80 104.73 137.31 91.27 116.31 71.49 84.24 140.35 

7 June i 156.48 188.63 154.70 120.50 163.50 71.80 106.89 110.42 137.05 176.61 69.34 101.97 112.77 92.19 128.87 78.36 90.30 125.11 

8 ii 142.49 172.46 191.60 131.30 171.13 112.94 164.07 144.26 149.03 150.38 103.44 126.77 78.52 133.73 168.59 52.98 79.97 146.24 

9 iii 187.16 138.04 191.40 177.90 197.91 123.20 144.24 164.69 160.93 150.85 82.54 184.62 106.23 129.15 195.32 85.72 111.12 182.08 

10 July i 173.62 175.53 174.60 183.60 179.21 116.55 158.56 185.04 172.72 164.07 130.81 137.20 159.02 162.77 175.75 83.75 146.24 183.88 

11 ii 168.24 146.49 189.50 187.60 172.58 151.91 135.11 176.48 168.36 179.52 119.19 126.87 169.92 176.21 170.97 145.77 161.64 176.42 

12 iii 133.87 151.62 194.18 172.73 190.22 164.08 156.06 182.07 162.70 180.25 117.61 162.95 170.90 175.57 188.82 157.43 171.51 178.39 

13 Aug i 151.13 142.85 194.20 148.40 179.73 175.48 186.68 157.52 179.52 150.03 182.93 175.78 178.88 152.00 174.54 134.23 173.79 175.21 

14 ii 150.51 186.39 163.80 156.40 148.21 162.02 185.67 164.90 165.34 176.85 188.00 187.28 192.63 173.33 130.90 161.87 228.80 122.63 

15 iii 185.56 191.66 175.36 159.09 181.22 188.73 195.02 188.66 191.68 178.86 190.91 196.60 195.23 184.33 192.58 116.85 142.90 144.84 

16 Sept i 188.08 122.90 166.60 184.70 196.28 188.87 195.42 185.64 189.92 179.76 177.62 195.46 193.33 182.68 193.77 131.41 155.73 182.75 

17 ii 197.77 195.10 196.70 196.00 197.80 191.76 169.09 150.76 173.19 192.51 175.36 151.81 163.53 171.22 141.39 146.44 121.58 192.93 

18 iii 183.26 189.40 192.60 170.90 178.45 188.86 155.28 122.17 196.13 193.57 133.70 193.97 135.09 137.96 177.31 156.19 91.92 189.06 

19 Oct i 151.36 160.50 162.40 142.80 181.97 152.48 125.55 108.97 169.50 173.54 113.62 193.54 110.27 99.35 163.01 110.10 182.51 156.44 

20 ii 119.07 138.10 134.50 101.70 107.69 108.64 98.99 87.30 137.99 131.59 136.43 149.61 87.82 82.95 135.30 75.24 177.25 140.14 

21 iii 93.12 107.91 112.09 98.82 192.48 97.51 88.79 75.31 103.56 102.85 98.42 122.68 72.71 83.10 117.68 59.51 166.33 111.79 

22 Nov i 75.50 87.20 86.20 95.00 172.35 83.29 77.42 68.59 85.67 86.81 77.23 95.35 65.45 67.98 95.07 62.72 134.82 94.66 

23 ii 67.54 77.90 70.90 95.90 144.47 70.70 64.18 58.70 75.35 74.65 65.31 79.98 56.00 63.06 82.41 65.42 115.27 84.81 

24 iii 58.40 68.10 67.20 85.10 218.27 63.74 60.26 58.28 70.01 64.71 58.16 72.64 53.35 57.56 75.73 51.86 99.39 76.10 

25 Dec i 52.74 62.80 60.90 108.70 106.61 61.15 55.24 51.26 61.20 65.52 57.00 63.52 51.25 52.37 67.99 44.05 86.91 70.16 

26 ii 50.31 58.60 57.70 116.40 90.36 57.89 51.97 90.54 55.80 63.96 52.58 59.82 47.93 53.73 61.41 40.47 76.60 65.28 

27 iii 51.29 55.45 57.55 89.00 77.47 50.61 45.93 86.42 52.29 57.64 48.12 53.56 41.43 46.38 55.81 37.18 75.76 55.64 

28 Jan i 49.72 51.10 53.16 77.20 75.55 48.80 47.32 42.03 50.71 49.41 48.77 56.69 38.56 45.98 47.55 38.58 78.69 57.04 

29 ii 53.29 70.00 51.86 72.70 67.97 58.91 42.89 40.24 47.82 49.18 14.18 65.05 35.92 50.82 45.81 36.09 68.65 62.14 

30 iii 47.87 60.55 48.81 63.09 72.43 61.35 40.05 40.07 48.67 72.79 0.00 56.32 32.96 43.80 47.28 33.18 58.56 50.81 

31 Feb i 43.95 38.40 47.21 56.80 65.12 66.29 37.24 50.35 50.91 66.03 0.00 52.46 33.28 48.24 46.43 41.19 56.94 49.02 

32 ii 86.78 0.00 53.25 59.50 62.40 85.54 36.43 77.27 78.15 56.38 0.00 51.02 52.38 49.10 52.42 39.78 69.01 49.11 

33 iii 53.32 0.00 44.98 115.88 63.54 61.20 39.59 1.00 74.68 0.00 0.00 48.56 45.92 51.31 47.66 41.30 66.74 53.90 

34 March i 57.06 76.80 59.48 155.00 57.36 60.92 36.17 0.00 106.15 33.37 36.32 45.45 76.70 63.39 44.00 38.81 65.49 58.08 

35 ii 51.53 97.20 71.53 174.20 52.77 66.19 36.48 0.00 70.50 61.32 128.29 65.14 139.80 66.14 39.95 41.83 68.85 55.78 

36 iii 110.58 130.55 86.51 165.64 53.65 92.23 52.75 107.18 85.35 59.21 121.97 61.18 133.92 51.17 44.21 53.24 73.36 74.47 

Month Average 108.92 114.33 118.77 124.86 141.40 102.08 104.96 96.15 122.09 111.72 87.39 111.25 101.51 100.70 106.59 75.28 104.66 111.03 

282


7.5 Annexure 5: 10 Daily Discharge KhodriPower Station 

Sl.no. 

10 Dialy 93-94 94-95 95-96 96-97 97-98 98-99 99-00 00-01 01-02 02-03 03-04 04-05 05-06 06-07 07-08 08-09 09-10 10-11 11-12 

Month Discharge 

1 April i 80.70 58.90 78.60 90.20 57.40 156.70 53.70 87.10 41.10 99.90 69.10 45.10 83.10 54.80 96.67 59.30 34.40 39.00 49.60 

2 ii 99.60 58.10 93.40 118.80 72.70 132.30 60.30 90.70 51.00 106.10 87.40 48.90 82.80 60.20 104.10 68.60 40.40 51.70 66.70 

3 iii 121.70 59.90 109.10 121.20 81.00 147.40 77.10 97.50 57.20 131.90 97.30 53.00 101.00 68.00 81.20 77.30 47.90 47.90 81.50 

4 May i 162.50 100.50 108.30 117.20 99.10 148.30 70.80 110.30 73.80 154.30 85.60 60.00 98.00 96.40 91.60 83.10 49.00 61.90 99.30 

5 ii 97.60 97.90 179.40 99.20 81.20 143.80 69.20 147.30 98.60 181.00 104.90 77.10 94.70 118.60 94.20 81.10 61.90 51.70 108.70 

6 iii 143.09 151.09 118.27 111.00 81.91 169.00 96.45 130.55 83.82 138.45 109.09 74.36 86.73 115.36 78.91 103.00 67.36 76.45 123.82 

7 June i 119.80 140.10 179.90 137.90 86.50 152.50 62.10 99.80 94.00 120.50 154.80 58.00 87.40 97.20 83.60 114.30 71.80 79.90 103.10 

8 ii 145.50 132.20 165.50 157.60 114.60 156.90 94.20 135.80 136.30 126.90 128.30 84.20 111.40 68.70 121.20 152.00 46.20 70.10 116.10 

9 iii 139.70 172.90 124.20 191.10 160.90 172.90 118.90 121.30 143.70 140.60 134.40 67.00 171.60 98.40 111.80 186.20 85.30 97.80 164.40 

10 July i 132.80 193.80 152.30 175.30 183.80 182.00 113.40 156.30 169.00 145.40 142.20 90.80 157.25 141.10 137.40 170.30 79.40 135.70 163.60 

11 ii 72.60 189.60 184.80 189.70 197.60 171.00 145.50 130.50 161.80 136.40 187.50 78.00 120.60 151.00 119.90 185.70 145.30 155.80 186.90 

12 iii 184.64 127.45 171.82 168.55 196.36 177.45 189.27 106.27 191.73 114.82 205.91 94.27 136.36 166.00 143.27 196.91 142.09 169.09 180.55 

13 Aug i 198.20 177.20 149.20 200.50 170.40 190.20 208.50 155.50 172.30 161.10 154.10 148.60 167.20 165.90 131.10 178.80 114.10 179.50 178.40 

14 ii 183.70 181.00 210.60 182.30 198.20 193.50 215.20 181.90 161.00 164.20 159.50 167.10 170.20 197.50 171.50 138.30 139.50 165.30 122.00 

15 iii 140.09 181.00 206.64 183.36 212.18 188.45 206.18 167.73 180.09 183.27 128.00 155.45 180.27 190.36 181.00 193.18 94.73 120.91 156.82 

16 Sept i 193.60 183.40 141.80 167.70 220.60 205.30 163.30 177.30 142.20 200.50 189.20 125.70 154.80 168.40 181.10 198.57 117.30 166.50 185.30 

17 ii 205.10 223.20 209.20 213.70 185.00 203.80 188.70 140.10 106.60 201.60 209.90 103.70 159.90 123.40 127.70 0.00 141.00 143.50 208.40 

18 iii 174.90 173.70 193.80 182.00 101.90 192.60 174.50 116.00 82.50 172.10 176.80 76.70 189.10 92.70 107.50 0.00 123.10 105.00 156.40 

19 Oct i 114.70 123.50 137.10 139.50 85.70 194.10 112.70 92.90 71.80 112.90 106.80 63.30 143.40 72.50 81.20 148.30 94.60 190.20 115.30 

20 ii 89.60 96.40 108.40 102.80 86.10 126.50 81.80 74.80 57.60 93.40 90.50 83.30 101.70 60.50 65.10 115.30 68.10 146.50 98.70 

21 iii 70.82 77.27 84.82 85.64 79.27 210.00 71.45 65.91 52.73 75.00 75.55 54.09 79.18 58.64 61.00 94.45 52.82 126.73 80.55 

22 Nov i 63.50 67.40 71.60 70.80 69.80 147.60 62.80 60.70 49.90 63.70 63.60 43.10 62.20 51.00 52.30 76.10 50.00 95.90 69.30 

23 ii 57.30 60.50 62.00 63.30 73.70 112.10 51.90 54.00 43.50 55.60 58.20 36.50 55.70 46.90 46.70 65.80 51.90 81.90 61.00 

24 iii 49.50 53.70 55.90 57.10 64.70 90.30 49.70 48.00 42.80 50.90 51.10 35.60 49.70 44.60 43.40 58.20 43.10 70.90 55.10 

25 Dec i 45.60 50.30 52.20 49.90 66.70 77.80 46.10 44.30 37.10 44.70 46.20 39.00 44.70 42.40 41.60 51.60 39.80 62.20 50.20 

26 ii 41.90 45.50 48.30 45.20 89.10 66.30 42.10 40.70 38.10 42.10 47.20 36.40 40.20 40.90 42.30 48.00 35.70 56.80 46.00 

27 iii 37.36 45.18 45.82 44.73 67.91 59.73 39.18 37.36 36.82 39.00 40.00 34.73 38.73 32.64 37.91 46.18 33.91 55.82 41.73 

28 Jan i 35.80 43.30 41.80 40.20 57.70 57.50 37.10 37.60 33.00 36.70 37.10 35.70 41.80 31.70 38.30 42.10 33.10 55.50 42.50 

29 ii 42.60 45.80 55.00 41.00 53.60 51.30 41.50 34.60 33.50 34.00 35.50 33.70 47.60 31.00 45.70 40.20 31.60 50.10 46.90 

30 iii 36.36 40.18 49.64 40.36 47.18 55.55 36.09 33.09 33.73 35.09 49.45 37.09 41.36 27.91 39.09 36.27 28.55 45.91 40.18 

31 Feb i 38.00 37.60 45.20 38.30 43.80 51.60 48.90 31.20 38.10 35.90 45.30 45.90 41.40 27.30 40.80 33.30 32.70 45.90 40.70 

32 ii 40.40 75.60 51.20 40.90 46.60 52.30 61.70 31.60 57.40 47.60 44.50 66.70 40.30 40.50 42.50 37.50 34.30 52.40 41.10 

33 iii 68.25 53.00 74.38 37.88 77.00 52.88 45.00 30.13 49.25 55.63 44.22 60.88 38.38 35.63 45.44 31.75 34.00 46.50 46.56 

34 March i 51.60 55.20 71.40 38.30 103.20 50.10 49.40 26.50 109.20 71.20 42.90 77.90 35.10 58.80 55.90 30.10 33.40 49.40 49.90 

35 ii 59.40 51.10 90.20 37.90 111.60 46.90 53.30 26.60 99.40 53.10 49.30 102.50 49.70 118.20 57.60 28.00 35.40 54.80 48.30 

36 iii 58.36 101.45 112.18 39.27 118.27 44.18 72.64 39.82 99.36 67.45 45.91 99.91 48.00 111.18 51.55 33.73 44.73 59.00 62.36 

Average Discharge 100.01 103.75 112.19 106.30 107.07 129.06 92.28 88.05 87.34 102.66 97.22 72.25 92.42 86.83 84.62 87.89 66.25 90.97 97.05 

283


7.6 Annexure 6: 10 Daily Discharge Kulhal Power Station 

Sl.no. Month 10 Daily 01-02 02-03 03-04 04-05 05-06 06-07 07-08 08-09 09-10 10-11 11-12 

Discharge 

1 April i 60.56 128.67 98.19 89.46 119.56 81.32 132.48 77.95 53.39 50.67 71.12 

2 ii 73.09 137.50 113.06 96.39 118.04 88.13 140.22 88.57 57.74 67.96 92.50 

3 iii 84.12 153.34 123.54 100.02 133.97 94.86 117.35 102.60 63.53 61.94 106.82 

4 May i 95.06 168.92 110.90 89.46 130.81 127.56 126.56 105.07 68.69 77.47 123.35 

5 ii 113.17 178.77 122.67 96.39 102.73 148.17 122.99 106.87 79.73 64.88 132.23 

6 iii 102.35 149.89 124.30 99.12 113.96 145.57 102.44 128.24 84.65 88.89 138.31 

7 June i 109.66 138.00 162.79 85.67 114.37 126.13 104.75 138.08 87.90 93.81 134.67 

8 ii 140.33 141.42 142.06 116.91 136.10 93.13 145.73 167.16 61.48 84.63 152.84 

9 iii 151.33 155.54 151.77 102.67 183.21 118.05 145.48 174.64 97.12 115.74 171.75 

10 July i 173.23 165.69 155.42 134.31 142.78 163.69 179.19 183.49 93.69 147.63 171.40 

11 ii 158.17 161.30 174.32 132.54 149.24 174.84 184.08 156.75 148.43 166.73 167.42 

12 iii 152.72 159.97 161.75 134.42 169.16 168.84 168.15 178.09 154.31 166.75 159.08 

13 Aug i 158.29 171.37 154.36 179.02 183.75 185.45 158.28 175.41 148.45 173.05 160.33 

14 ii 149.82 166.23 177.38 188.49 185.48 190.94 183.27 127.52 169.81 166.09 135.16 

15 iii 169.85 189.01 186.35 191.50 185.50 192.63 183.26 187.34 130.74 40.68 134.56 

16 Sept i 178.41 186.40 181.46 187.02 191.35 193.92 185.79 192.77 143.28 126.26 181.09 

17 ii 159.55 176.39 188.45 182.84 155.99 179.31 185.53 156.21 153.87 130.50 178.81 

18 iii 241.84 189.02 180.63 149.01 185.74 145.83 157.67 177.36 163.05 133.62 190.29 

19 Oct i 109.74 172.25 182.17 129.66 195.25 122.68 118.99 172.38 128.95 195.39 170.16 

20 ii 91.35 143.11 153.49 149.54 168.40 102.95 102.46 153.08 87.95 189.70 164.42 

21 iii 83.58 108.48 122.87 114.72 138.49 94.90 101.18 133.30 66.87 182.54 131.86 

22 Nov i 81.26 93.23 107.99 93.23 113.87 81.96 86.89 109.76 76.00 152.61 114.89 

23 ii 66.66 86.35 98.33 77.76 97.42 72.45 77.68 99.83 80.00 132.98 102.64 

24 iii 63.46 84.48 88.33 74.86 92.54 70.06 68.84 94.20 67.98 119.06 92.14 

25 Dec i 58.96 75.66 79.59 73.41 77.87 68.01 64.55 86.97 61.35 106.90 82.79 

26 ii 59.57 70.46 81.77 66.31 77.14 64.25 71.95 79.91 55.51 96.08 78.26 

27 iii 56.01 62.28 70.11 61.13 70.15 58.06 60.55 71.69 51.19 89.07 69.77 

28 Jan i 50.35 60.11 64.85 60.26 73.94 53.24 65.03 63.51 50.93 94.15 71.67 

29 ii 50.93 54.65 61.72 27.45 79.16 51.48 71.95 60.38 47.91 86.33 77.63 

30 iii 50.82 56.00 86.43 7.21 70.33 46.68 62.93 60.35 46.77 75.92 70.79 

31 Feb i 58.36 60.79 76.81 0.00 65.90 51.07 65.16 58.76 54.15 74.75 67.22 

32 ii 81.00 71.13 73.44 0.00 64.90 73.36 63.84 61.11 52.28 81.79 66.87 

33 iii 1.88 89.28 0.00 0.00 63.37 61.43 65.03 50.43 50.50 79.00 68.24 

34 March i 0.00 107.98 38.58 37.93 59.85 94.10 72.11 49.56 47.18 75.63 76.12 

35 ii 0.00 85.27 63.62 145.84 81.03 148.27 79.24 45.90 48.37 76.41 73.98 

36 iii 105.23 98.54 61.94 137.85 74.45 147.73 64.46 52.08 61.90 84.90 88.10 

Month Average 98.97 124.04 117.07 101.01 121.52 113.81 113.49 115.02 86.17 109.10 118.63 

284


7.7 Annexure 7: 10 Daily Discharge Chilla Power Station 

Sl.no. Month 02-03 03-04 04-05 05-06 06-07 07-08 08-09 09-10 10-11 11-12 

1 April i 310.10 269.80 175.10 253.40 156.60 308.20 315.00 328.90 335.90 469.70 

2 ii 363.70 356.60 187.10 273.00 169.60 330.20 336.40 355.50 409.80 508.30 

3 iii 426.80 320.10 227.20 362.40 196.60 334.30 375.70 384.30 386.50 589.70 

4 May i 409.70 339.10 229.00 408.50 296.00 413.80 402.40 417.40 378.00 623.30 

5 ii 406.60 418.00 349.00 429.50 453.00 474.30 428.10 409.30 352.00 631.30 

6 iii 375.18 507.36 429.18 376.00 526.55 367.00 493.45 465.09 423.55 608.82 

7 June i 369.80 525.90 439.40 417.20 551.70 453.40 533.00 492.40 486.70 615.50 

8 ii 207.70 492.00 462.40 477.00 541.30 560.60 455.40 378.40 436.80 621.90 

9 iii 295.00 496.30 526.20 414.60 467.60 567.00 461.90 395.50 557.40 603.40 

10 July i 454.90 502.30 500.50 426.70 578.80 526.30 466.00 542.30 558.10 608.30 

11 ii 532.40 541.30 567.20 471.20 554.80 552.20 474.00 555.10 556.10 602.10 

12 iii 524.64 565.64 502.45 517.64 556.36 524.27 530.45 510.55 559.55 566.73 

13 Aug i 524.90 544.20 518.10 537.50 581.30 494.90 556.70 540.70 566.30 569.20 

14 ii 453.20 560.10 547.20 534.40 599.20 460.00 545.70 533.00 543.00 399.90 

15 iii 532.82 539.45 567.18 549.09 600.00 482.27 554.91 487.55 526.73 568.18 

16 Sept i 510.60 510.90 582.20 558.90 560.00 567.00 545.80 460.40 392.10 582.50 

17 ii 496.60 519.00 593.60 520.30 600.00 567.00 555.30 464.40 391.60 593.60 

18 iii 543.20 567.00 571.00 539.70 592.90 544.70 539.80 430.30 461.70 631.50 

19 Oct i 550.90 563.30 571.00 556.90 498.90 560.30 551.70 378.30 584.80 586.70 

20 ii 504.00 514.80 573.20 547.40 383.40 484.80 473.20 314.60 576.10 597.40 

21 iii 419.27 429.36 493.45 476.09 366.18 453.09 388.45 349.55 547.36 542.64 

22 Nov i 314.30 373.90 387.20 295.70 356.60 426.40 368.00 306.50 467.90 463.70 

23 ii 258.20 318.40 329.90 244.40 281.40 402.10 349.30 343.20 400.70 370.80 

24 iii 276.40 266.50 288.40 208.60 290.10 364.10 343.00 291.40 381.20 367.50 

25 Dec i 258.00 245.00 258.60 188.00 291.00 368.50 355.00 298.30 370.70 392.10 

26 ii 224.50 240.30 232.50 180.50 287.00 354.50 333.40 300.90 309.60 368.60 

27 iii 215.09 217.64 216.91 183.36 282.91 357.00 354.45 315.18 195.36 359.00 

28 Jan i 209.60 203.30 205.60 179.70 268.40 376.50 403.20 357.10 191.90 389.10 

29 ii 198.00 194.30 196.70 181.40 249.70 384.50 383.30 377.30 175.00 426.00 

30 iii 193.36 203.00 204.45 173.36 242.18 380.91 386.27 338.00 216.27 378.73 

31 Feb i 204.50 192.50 228.80 170.00 257.10 384.40 341.20 349.60 371.90 407.70 

32 ii 15.60 183.30 261.20 165.70 270.50 378.50 354.50 376.50 426.10 410.70 

33 iii 0.00 183.00 243.00 164.75 242.38 354.67 362.75 360.75 408.38 383.22 

34 March i 46.90 154.10 250.90 160.60 275.60 344.60 335.40 355.90 428.30 394.10 

35 ii 228.00 183.20 243.90 164.10 341.20 350.20 323.70 406.10 457.30 375.60 

36 iii 262.82 181.18 273.09 124.55 351.36 329.55 319.36 394.91 456.00 409.73 

Average 338.89 373.43 374.05 346.28 393.49 432.68 425.38 399.43 424.59 500.61 

285


7.8 Annexure 8: 10 Daily Discharge Khatima Power Station 

Sl.no. 01-02 02-03 03-04 04-05 05-06 06-07 07-08 08-09 09-10 10-11 11-12 

1 April i 121.24 155.17 171.08 105.75 147.06 107.40 192.01 124.20 103.28 145.06 106.38 

2 ii 136.57 162.89 207.58 105.83 160.59 131.49 197.18 134.45 116.91 167.77 110.76 

3 iii 163.22 209.78 224.04 154.32 199.48 138.07 196.84 160.02 126.85 177.28 126.11 

4 May i 227.06 219.31 218.85 155.83 218.59 199.67 211.48 178.59 166.66 195.71 166.44 

5 ii 244.95 294.34 236.88 189.73 215.32 242.39 228.26 188.53 144.21 170.86 180.41 

6 iii 222.62 300.79 256.68 220.17 237.70 251.69 217.42 218.97 220.71 193.64 208.07 

7 June i 239.78 227.40 218.85 216.61 232.00 252.20 191.55 232.38 235.21 217.60 208.20 

8 ii 227.74 246.02 236.88 230.16 284.95 235.07 305.83 287.44 168.17 218.25 234.47 

9 iii 269.82 250.37 256.68 267.21 297.47 229.00 273.74 308.43 269.60 267.91 241.17 

10 July i 257.46 263.16 280.57 308.96 307.39 273.17 301.12 266.54 276.80 274.93 237.69 

11 ii 308.96 243.54 296.19 324.88 291.74 313.13 313.13 294.87 318.53 303.14 207.99 

12 iii 310.28 239.25 262.05 326.18 317.88 311.70 292.55 287.05 318.61 271.57 221.53 

13 Aug i 311.04 273.81 297.10 326.18 315.75 313.13 269.81 289.64 291.50 274.85 212.07 

14 ii 317.83 305.56 290.22 326.18 322.53 313.13 284.70 270.34 282.61 190.34 

15 iii 308.38 285.85 288.88 326.18 318.83 313.13 305.07 168.03 301.68 

16 Sept i 322.00 294.84 299.48 326.18 323.58 313.13 293.82 193.93 304.65 

17 ii 307.39 281.74 220.31 326.18 316.79 313.13 319.40 300.58 301.99 

18 iii 317.30 289.96 178.31 301.92 233.28 323.58 256.25 178.20 297.98 

19 Oct i 315.74 299.99 178.40 326.18 310.52 323.58 317.31 238.98 210.38 

20 ii 244.77 294.80 271.56 315.74 313.13 305.30 266.43 297.69 115.11 

21 iii 169.94 243.24 253.31 228.67 195.02 207.71 159.31 217.45 117.30 

22 Nov i 159.74 198.33 176.27 204.86 175.25 180.75 159.31 144.47 132.54 

23 ii 196.13 205.98 176.84 195.03 188.44 167.39 171.13 163.82 129.39 

24 iii 185.14 191.73 158.57 192.83 175.25 135.08 164.45 174.70 152.83 

25 Dec i 160.96 184.59 151.92 149.53 167.23 123.79 163.74 199.84 181.57 

26 ii 147.94 158.39 149.51 138.05 151.95 142.75 169.67 191.38 197.80 

27 iii 129.67 131.89 134.06 146.61 148.35 129.64 160.36 173.87 177.60 

28 Jan i 118.77 140.85 132.99 137.06 144.48 121.98 144.48 146.27 172.06 

29 ii 132.17 115.97 124.45 137.28 135.58 112.05 141.02 132.12 158.38 

30 iii 116.54 117.07 129.49 164.56 126.91 101.26 133.01 130.65 137.27 

31 Feb i 113.91 142.50 120.93 162.69 117.66 90.51 134.09 130.63 135.66 

32 ii 134.10 130.24 117.94 179.65 111.60 134.22 132.37 129.39 158.38 

33 iii 122.85 140.52 119.25 171.82 107.86 103.65 123.04 108.63 141.46 

34 March i 149.59 176.24 104.82 149.92 93.40 144.65 119.96 107.44 148.43 

35 ii 138.30 162.83 118.93 178.46 109.71 161.96 123.22 111.43 131.26 

36 iii 144.30 172.35 116.83 177.50 106.39 180.74 123.13 107.51 139.98 116.05 103.26 

Month Average 208.17 215.31 199.35 219.30 211.66 206.70 209.89 194.12 193.98 213.90 183.66 

286


7.9 Annexure 9: 10 Daily Discharge Maneri Bhali – II Hydroelectric Project 

Sr. No Month 

10 Daily 

Average 2008-09 2009-10 2010-11 2011-12 

1 April 1 29.03 30.05 37.81 

2 2 34.97 57.13 48.93 

3 3 44.32 56.06 65.36 

4 May 1 53.56 79.95 88.61 

5 2 70.01 69.12 112.29 

6 3 116.15 100.87 109.16 

7 June 1 122.54 113.46 102.99 

8 2 105.85 97.66 126.91 

9 3 115.09 131.13 98.85 

10 July 1 129.14 113.25 117.17 

11 2 103.42 112.46 124.69 

12 3 91.13 121.96 120.37 

13 Aug 1 58.17 108.99 101.36 

14 2 77.03 78.19 90.93 

15 3 118.62 107.57 104.24 

16 Sept 1 97.90 111.44 110.37 

17 2 115.04 103.40 111.22 

18 3 100.32 88.39 122.59 

19 Oct 1 97.78 99.53 121.23 112.00 

20 2 76.26 65.53 104.47 79.89 

21 3 63.37 53.93 84.62 62.03 

22 Nov 1 55.98 44.81 65.44 53.62 

23 2 50.30 39.55 57.11 47.42 

24 3 45.86 36.64 49.23 41.58 

25 Dec 1 39.71 32.26 42.59 38.74 

26 2 38.01 30.34 38.85 34.07 

27 3 35.24 26.21 35.64 29.54 

28 Jan 1 33.36 27.69 33.87 30.20 

29 2 31.00 27.20 31.21 33.08 

30 3 29.71 26.93 29.73 30.72 

31 Feb 1 28.21 26.27 28.06 30.34 

32 2 25.43 27.18 31.54 29.22 

33 3 25.49 29.74 29.03 28.54 

34 March 1 26.63 28.64 28.70 32.14 

35 2 26.69 33.85 34.32 33.03 

36 3 27.82 45.23 39.01 41.96 

Average 42.05 63.44 71.27 71.72 

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 

Estimated cost of 

balance works, which 

Estimated 

S.No. 

Particulars of works 

were included in the 

Amount 

Remarks 

approval accorded by 

(in Lakhs) 

CEA 

1 Rehabilitation 1555.94 During commissioning of the project, habitants of Joshiyara, 

Gyansu and Malin Basti demanded to consider the submerge 

area upto El 1110 m instead of El 1108 as mentioned in DPR. 

Earlier, it was proposed to construct the protection wall upto 

El 1108 m on the periphery of Joshiyara Reservoir on the 

required locations. But habitants of Joshiyara, Gyansu and 

Malin Basti also demanded to construct the protection wall 

upto El 1110 m. At last, this project was commissioned on 

16 th Feb, 2008 at barrage level of El 1104 m, instead of 

Maximum Pond level El 1108 m as given in DPR. Therefore, 

288




Estimated 

S.No. 



Amount 

Remarks 


(in Lakhs) 

CEA 

this cost involved in rehabilitation was not included in the 

earlier approved proposal accorded by CEA. 

2 Compensation for the 

affected people 

113.55 Due to Joshiyara Reservoir, 0.532 Ha land of Gyansu & 

Joshiyara villagers have been submerged without acquiring 

their land. At present, Maneri Bhali Stage-II Project is 

completely and all properties of project are in the possession 

of UJVN Ltd. Therefore, their compensation will also be paid 

by the Nigam. There are 9 affected people/family of Gyansu 

village & Joshiyara Village, who had not got the land 

compensation and one owner, who had not got the 

compensation against his building. 

In addition to the above compensation, it was decided in the 

289




Estimated 

S.No. 



Amount 

Remarks 


(in Lakhs) 

CEA 

meeting of Chief Secretary, GoU with the Affected People 

held on 04.03.2008 that an amount equal to one year rent 

should be paid to affected owner of the building due to 

Joshiyara Reservoir, so that they can live during construction 

their house. 

The cost of the above compensation was not included in the 


3 Construction of Protection 

wall 

850 3231.54 The reasons for increase in the construction cost are as under: 

Earlier, It was proposed upto El 1108 m only but as pet the 

demand of the affected people, it is proposed upto El 1110 m. 

It was proposed in the required location only. Now, it is 

290




Estimated 

S.No. 



Amount 

Remarks 


(in Lakhs) 

CEA 

proposed almost all around the Joshiyara reservoir. 

Earlier estimate was based on 2007 schedule of rate. Now it is 

based on the current schedule. 

4 Modification of tail race 

channel 

2415.00 On 16th Feb, 2008, Maneri Bhali Stage-II project was 

commissioned and handed over in the service of nation. 

After the availability of water to run all the four machines 

at full load in July-2008, excessive vibrations on the 

machines were observed by UJVNL and BHEL Engineers 

because The existing tailrace configuration is not suitable 

for proper evacuation of the flow from all the turbine units 

running at full load. 

This work was not included in the earlier approved 

291




Estimated 

S.No. 



Amount 

Remarks 


(in Lakhs) 

CEA 

proposal accorded by CEA. 

5 Construction of Office 

Building at Joshiyara 

6 Construction of Joshiyara 

colony 

5.00 102.74 Initially, it was decided that the all works shall be looked after 

from the main office of MB-II, Chinyalisaur. But during 

operation of Joshiyara Barrage, it has been experienced that 

the Executive Engineer (Civil) may look after the works of 

barrage operation efficiently from Joshiyara. Therefore, a 

permanent office for Executive Engineer (Civil) is also 

proposed in Joshiyara, which was not included in the earlier 

approved proposal accorded by CEA. 

109.77 Affected People demanded to rehabilitate in the Project land 

and the District Administration also requested to shift them in 

the area where temporary residences exist. Therefore, these 

292




Estimated 

S.No. 



Amount 

Remarks 


(in Lakhs) 

CEA 

residences have been demolished. 

Hence, some residences are required to accommodate the 

officers/staff posted at Joshiyara Barrage. 

7 Construction 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) 

8 Construction of 

Infrastructure works for 

15.9 222.18 Police line and Gyansu village are situated on the right bank of 

the Joshiyara reservoir. There is no direct road from police 

line to Uttarkashi city. Therefore, residents of the police line 

and gyansu villagers are using our barrage road. So, there is 

an urgent requirement of road from Barrage to NH-108 for 

safety point of view, which was not included in the earlier 


950.00 The works proposed to fullfill the demands of the affected 

People of Joshiyara Village, Gyansu and Malin Basti come to 

293




Estimated 

S.No. 



Amount 

Remarks 


(in Lakhs) 

CEA 

affected villagers from 

the notice after submission of the proposal to CEA. Therefore, 

Joshiyara, Gyansu and 

the cost against these works was not included in the earlier 

Kansain village as per their 


demands 

9 Construction of boundary 

14.90 

It is proposed after submission of the proposal to CEA for the 

wall, security fencing and 

safety of the residential colony at Chinyalisaur because due to 

gate for Shaktipuram 

120.59 

the non existence of the security fencing/boundary wall, the 

colony and Shifting of 

entry of the unwanted peoples in the colony is very easy 

existing boundary wall of 

resulting in thefts and the feeling of insecurity to the residents 

Shaktipuram colony and 

of the colony. Therefore, the cost against these works was not 

provide the separate way 

included in the earlier approved proposal accorded by CEA. 

for villagers behind 

Shaktipuram colony 

294




Estimated 

S.No. 



Amount 

Remarks 


(in Lakhs) 

CEA 

10 Construction of 04 Nos 

Type-IV Residences and 01 

Nos Type-V Residence in 

Shaktipuram Colony, 

Chinyalisaur 

11 Construction of school 

building for Saraswati 

Shishu Mandir School in 

Shaktipuram Colony 

Chinyalisaur 

12 Strengthening of water 

distribution system of 

15.00 109.77 As per the new structure of the staff at MB-II Power House 

and demolition of old & temporary quarters, new quarters are 

required to accommodate all officers/staffs, which cost was 

not included in the earlier approved proposal accorded by 

CEA. 

199.79 Saraswati Shishu Mandir School in Shaktipuram Colony, 

Chinyalisaur is established for more than 30 years ago in 

temporary type quarters. In the later stage, it is decided to 

construct the new school building, which cost was not 

included in the earlier approved proposal accorded by CEA. 

66.87 88.57 Enhance the cost of these work is due to escalation only. 

295




Estimated 

S.No. 



Amount 

Remarks 


(in Lakhs) 

CEA 

Shaktipuram 

Chinyalisaur 

colony, 

13 Construction of workshop 

building at Dharasu power 

house of MB-II project 

14 Protection work on hill 

slope behind power house 

150 168.78 Enhance the cost of these work is due to escalation only. 

257.00 Initially, some protection works of Dharasu Power House had 

been done by Irrigation Department. But just before the 

commissioning of the Project, the protection works failed at 

some point. Therefore, it is decided to re-protect these works 

against the capital expenditure. It is also to inform that the 

cost against this work was not included in the earlier 


296




Estimated 

S.No. 



Amount 

Remarks 


(in Lakhs) 

CEA 

15 Testing of surge shaft gate 500.00 The surge tank gate has been installed during running 

condition of Power House, so that testing of this gate has not 

been done till to-date. At present, the testing of gate shall be 

made possible with the help of Mixed Gas Diving or Saturation 

diving for deeper zone upto 103 m deep water as per the 

requirement of site for complete sealing of Gates. 

It is also to inform that the cost of this work was not included 

in the earlier approved proposal accorded by CEA. 

16 Centage Charges 

6084.00 

GoU directed to release the payment to Irrigation Department 

against centage charges in the later stage. Therefore, the cost 

involved in this was not included in the earlier approved 

proposal accorded by CEA. 

297




Estimated 

S.No. 



Amount 

Remarks 


(in Lakhs) 

CEA 

17 Payments to M/s NPCC 

against claims of Principal 

Agreement in accordance 

to the decision of High 

Power Committee 

5000.00 1268 

18 Liabilities against major 

civil contract of MB-II 

Project 

(a) 

Reimbursement of Sales 

Tax 

815.32 Initially the project authority didnot release the payment 

against reimbursement of the Sales Tax. But it is being 

reviewed that this payment is payable or not as per the terms 

of condition of the contract. Therefore, the cost involved in 

298




Estimated 

S.No. 



Amount 

Remarks 


(in Lakhs) 

CEA 

this was not included in the earlier approved proposal 

accorded by CEA. 

(b) Reimbursement of royalty 45.13 Initially the project authority didnot release the payment 

against reimbursement of the Royalty. But it is being reviewed 

that this payment is payable or not as per the terms of 

condition of the contract. Therefore, the cost involved in this 

was not included in the earlier approved proposal accorded 

by CEA. 

(c) Award given by the 

arbitrator in favour of M/s 

Hydel Construction (P) Ltd 

against dispute related to 

6000.00 3073.00 

299




Estimated 

S.No. 



Amount 

Remarks 


(in Lakhs) 

CEA 

swellex Rock Bolt, Steel 

Fibre as Extra Item and loss 

due to flood alongwith 

interest of Rs 95424/- per 

month 

(d) Payment against misc. 

Works 

26.03 

(e) Security 35.00 

(g) Pending payment of GSI 95.32 GSI raised their bills after commissioning of the project. 

Therefore, the cost involved in this was not included in the 


(g) Expenditure incurred for 3.00 35.00 Due to increase the number of arbitration cases. 

300




Estimated 

S.No. 



Amount 

Remarks 


(in Lakhs) 

CEA 

arbitration 

Total 12120.00 21623.00 

301


7.11 Annexure 11: Nature of Environmental Impacts caused by RMU and suggested mitigation measures 

Impact Area Impacts on Environmental Impact Mitigation Measures 

Soil and land 

Land take for reservoir 

Dumping of dredged silt in identified areas followed by 

(DAM & Head 

sediment disposal (muck), 

proper reclamation of the dumping sites. Alternatively, 

race tunnel) 

sediment flushing in smaller portions during monsoon 

period into river may be preferred. Special sediment 

Dam 

including 

flushing procedure to be developed. 

colony, desilting 

chamber, 

Head Race 

Tunnel & 

Barrage 

Geology 

(Head race 

tunnel) 

Soil and land 

(BARRAGE) 

Excavation of rock for 

additional underground tunnel 

Permanent land take for 

dumping of reservoir 

sediments: 

To be taken up only after detailed geological 

investigation keeping in view the fragile geology 

encountered at the time of initial construction of the 

project. 

Adequate engineering measures such as terraces and 

retaining walls should be implemented while dumping 

the dredged silt in identified areas, with proper 

reclamation and landscaping of dumping sites. 

Soil and land Soil pollution from handling of For dismantling and handling of oil containing equipment 

302



(DAM 

& 

oil (fuel, equipment) 

construction solutions should be developed. 

BARRAGE) 

Local 

climate 

Threats on air caused by 

Sprinkling of water at the construction site and on the 

and air 

dismantling: Dust from cement, 

transportation route; proper maintenance of project 

sand, excavation, induced by 

vehicles. 

heavy machines and vehicles 

etc. 

Water quality 

Noise 

environment 

Pollution of water quality due 

to the chemicals and fluids 

from vehicles, equipment to be 

dismantled 

Noise due to construction 

activities including increased 

vehicular movement 

For dismantling and handling of oil containing equipment 

special construction solutions have to be developed. This 

would include proper storage and disposal of all waste 

generated during the project work in compliance with 

the existing rules and regulations. 

Restriction of noise generating activities at night, use of 

noise barriers, and proper maintenance of vehicles and 

machineries. 

Fish stocks Degradation of natural fish Mandatory provision of minimum downstream discharge 

303



stocks by dismantling and 

for ecological and social reasons 

construction works 

Health 

and 

Injury and sickness of project 

Preparation and implementation of health and safety 

safety 

personnel and local residents 

plan. Use of personal protective gears, availability of first 

due to accidents/fires and 

aid kits at site and arrangements with local 

natural hazards 

hospitals/dispensaries for emergency care. 

Powerhouse 

including units, 

transformers 

and switchyard 

Soil and land Permanent land take for 

dumping of tunnel muck : 

Approximately 600,000 m³ 

(incl. muck of Khodri HRT) 

Soil pollution from handling of 

oil (fuel, equipment) 

Local climate Threats on air caused by 

and air 

dismantling: Dust from cement, 

sand, excavation, induced by 

heavy machines and vehicles 

Dumping of excavated muck in identified areas only 

followed by proper reclamation of the dumping sites 


construction solutions should be developed. 

Sprinkling of water at the construction site and on the 

transportation route; proper maintenance of project 

vehicles. 

304



etc. 

Water quality 

Noise 

environment 

Change of water quality due to 

the chemicals and fluids from 

transformers, vehicles, heavy 

machines etc. 

Noise due to construction 

activities including increased 

vehicular movement 


construction solutions should be developed. This would 

include proper storage and disposal of all waste 

generated during the project work in compliance with 

the existing rules and regulations. 

Restriction of noise generating activities at night, use of 

noise barriers, and proper maintenance of vehicles and 

machineries. 

Fish stocks Degradation of natural fish 

stocks in Tons River by 

dismantling and construction 

works 

Mandatory provision of minimum downstream discharge 

for ecological and social reasons. 

Health 

and 

Injury and sickness of project 

Preparation and implementation of health and safety 

safety 

personnel and local residents 

plan. Use of personal protective gears, availability of first 

due to accidents/fires and 

aid kits at site and arrangements with local 

305



natural hazards 

Geology Excavation of rock for 

additional underground tunnel 

hospitals/dispensaries for emergency care. 

To be taken up only after detailed geological 

investigation keeping in view the fragile geology 

encountered at the time of initial construction of the 

project. 

306


7.12 Annexure 12: Financing of RMU of Six Hydro Electric Projects Through KfW 

INTRODUCTION 

UJVN Ltd. has submitted the project cost for Modernization and Upgradation of six HEPs in the State of Uttarakhand which have been 

identified for funding under Loan from KfW available through Loan and Financing Agreement signed between kfW and PFC, on the basis 

of Bilateral Agreements executed between the Governments of India and Germany. 

1. Bilateral Agreement 

The Development Policy of the Federal Republic of Germany aims at improving economic and social living conditions in the developing 

countries. This goal is pursued chiefly by bilateral, government-to-government cooperation. The Bilateral Agreements on Financial Cooperation 

between the Govt. of Federal Republic of Germany and the Govt. of India were signed on 28.07.1994, 05.06.1997, 

04.10.2002 and 09.12.2005. The Financial Cooperation is carried out by KfW (Kreditanstalt für Wiederaufbau), on behalf of the German 

Federal Government. 

2. Loan and Financing Agreements 

On the basis of Bilateral Agreements, PFC and KfW had entered into a Loan and Financing Agreement on 28.12.2005, as per which KfW 

shall extend to PFC a composite loan of 100,564,594.06 EUR (Soft loan, Portion I- 35,564,594.06 EUR and Commercial Loan, Portion II- 

65,000,000.0 EUR) and Financial Contribution (as grant) of 3,333,875.64 EUR. PFC shall further use this loan exclusively to fund subloans 

for the purpose of partial funding of the investment costs of the rehabilitation and modernization of the electro-mechanical part 

307


of older Hydro-Electric Plants (HEPs) in reform-oriented States of India as identified by PFC and services of the pertaining 

implementation consultant. 

The project activities eligible for financing from the loan shall be: 

• Rehabilitation, modernization and up-gradation of electro-mechanical equipment and civil works of hydro power stations 

• Consulting services of the Implementation Consultant 

Financial Contribution shall be used exclusively for expert and seminar services. The project activities eligible for financing from the 

Financial Contribution shall comprise: 

• Consulting Services for preparation of Feasibility Studies (EUR 1,800,000) 

• Expert Services (EUR 1,033,875.64) 

o Panel of Experts (EUR 333,875.64) 

o Long-Term Experts (EUR 700,000) 

• Seminars (EUR 500,000) 

Interest Rate, Repayment Period and Commitment Charges 

The interest rate, repayment period and commitment charge, as applicable on soft loan (Portion I) and commercial loan (Portion II), as 

per financial terms of lending the proceeds from the KfW Line of Credit to PFC are as follows: 

Commercial Loan (Portion II) Soft Loan (Portion I) 

Amount (in EUR Million) 65.00 35.564 

308


Commercial Loan (Portion II) Soft Loan (Portion I) 

KfW Interest Rate EURIBOR + 1.3% 0.75% (Fixed) 

Repayment period (as per original 

agreement) 

7 years 28 years (Starting after repayment of commercial 

loan) 

Repayment period (as per original 

agreement) 

30 th June 2011 – 30 th Dec 

2017 

30 th June 2018 – 30 th Dec 2045 

Repayment period (Revised) 30 th June 2014 – 30 th Dec 

30 th June 2018 – 30 th Dec 2045 

Commitment Charges 

2020 

0.25% p.a. on undisbursed 

loan amounts of each sub 

loan of portion II. It shall be 

computed for a period 

beginning three months from 

the date KfW approves in 

writing the re-financing of an 

individual sub-project from 

portion II and ending at the 

date at which disbursements 

are debited. 

0.25% p.a. on undisbursed amounts of portion I. It 

shall be computed for a period beginning three 

months after signing of the loan and financing 

agreement and ending at the date at which 

disbursements are debited. 

The salient features of Loan and Financing Agreement between KfW and PFC are as follows: 

309


• As per clause 2.2, the last date of drawl was December 30, 2010. The clause no. 2.2 has been amended and the last date of drawl 

is now December 30, 2015. 

• Taxes and other public charges to be borne by the Sub-borrowers and import duties would not be financed from the sub-loans. 

• As per clause 3.5, PFC shall pay the commitment charge, interest and any other charges on arrears semi-annually on June 30 and 

on December 30 of each year for the half year then ending. The commitment charge shall become due for the first time together 

with the first interest payment. 

• As per Article 6, to furnish security for the loan, the Republic of India (Guarantor) shall enter into separate Guarantee Agreement 

with KfW. 

Further, following major amendments are proposed to be made in the Loan and Financing Agreement between KfW and PFC: 

1. Extension of last disbursement date from 30.12.2010 to 30.12.2015. 

2. Extension of repayment commencement date of Portion-II of the loan from 30.06.2011 to 30.06.2014. 

These amendments have been approved by Ministry of Power, GoI and forwarded to Dept. of Economic Affairs, Ministry of Finance, 

GoI for their approval. Sanction of loan is proposed to be subject to signing of amendments (as cited above) to Loan and Financing 

Agreement between PFC and KfW. 

3. Counter Guarantee cum Guarantee Fee Agreement 

In accordance with the provisions of the Loan and Financing Agreement between PFC and KfW, a Guarantee Agreement was signed 

between KfW and the Govt. of India (GoI) on 17.05.2006 whereby GoI has guaranteed the due and punctual repayment of principal, 

interest and other charges, including premium in case of pre-payment, to KfW. Accordingly, a Counter Guarantee cum Guarantee Fee 

310


Agreement was signed between the Government of India (Ministry of Power, GoI) and PFC on 22.02.2008. The salient features of this 

Agreement are as follows: 

• The borrower (PFC) undertakes to pay the guarantor (GoI), in advance, a guarantee fee of zero point two percent (0.2%) p.a. on 

the sums guaranteed. 

• The payment of guarantee fee shall become due on the principal amount of loan withdrawn and outstanding including 

accumulated interest thereon and commence from the date of signing of the Guarantee agreement with KfW (i.e. 17.05.2006). 

• Thereafter for any subsequent financial year, the payment of guarantee fee would be made at the applicable rate on the principal 

amount of loan withdrawn and outstanding including accumulated interest thereon, on 1 st day of April next financial year. 

• The guarantee fee shall be calculated in EURO and paid in Rupees at the rate of exchange prevailing on 31 st March of the financial 

year for which the guarantee fee is payable. 

4. Memorandum of Agreement between PFC and UJVNL 

Due to strong interest shown by UJVNL in modernization and upgradation of its obsolete HEPs and fulfilment of eligibility criteria set by 

KfW and PFC for funding of projects, it was decided to concentrate the funds on UJVNL. Subsequently, a Memorandum of Agreement 

(MoA) was signed between PFC and UJVNL on 17.12.2005 for utilizing the above mentioned KfW Loan and Financial Contribution for 

Modernization and Upgradation of older HEPs. Certain amendments to MoA are proposed to be signed between PFC and UJVNL after 

taking note of changes in Loan and Financing Agreement. UJVNL vide letter dated 04.05.2012 have agreed to sign such amendments. 

The financial terms of on-lending the proceeds from the line of credit from KfW are as follows: 

Commercial Loan 

KfW Interest Rate EURIBOR + 1.3% 0.75% (Fixed) 

Soft Loan 

311


PFC Margin 1.00% 1.00% 

Total Interest Rate (Payable Semi-Annually) EURIBOR + 2.3% 1.75% 

Repayment period offered by PFC to UJVNL (as per 7 years 5 years (Starting after repayment of 

original agreement) 

commercial loan) 

Repayment period (as per original agreement) 30 th June 2011 – 30 th Dec 

2017 

30 th June 2018- 30 th December 2022. 

Repayment period offered by PFC to UJVNL (as per 

proposed amendments to MoA) 

7 years 11 years 

Repayment period (as per proposed amendments to 

MoA) 

30 th June 2014 – 30 th Dec 

2020 

30 th June 2018- 30 th December 2028. 

Commitment charges 

Taxes 

Govt. of India Guarantee fee 

(Reduced from 1.20% p.a. to 0.2% p.a., the benefit of 

reduction of guarantee fee is passed on to UJVNL) 

On actuals (the entire commitment charges payable by PFC to KfW as per the 

LFA shall be reimbursable by UJVNL to PFC) 

Additional charges, taxes and duties including withholding tax applicable if 

any, on borrowed funds under LoC are payable at actual by UJVNL 

0.20% p.a. on the principal amount of loan withdrawn and outstanding 

including accumulated interest thereon by UJVNL which will be paid by UJVNL 

at the beginning of financial year till the end of repayment period of 35 years. 

The R&M Projects in Uttarakhand identified for utilization of KfW loan are as follows: 

312


Chibro Khodri Tiloth Dhakrani Dhalipur Kulhal 

Capacity (MW) 4X60 4X30 3X30 3X11.25 3X17 3X10 

Project Cost (EUR Mn) 27.59 25.30 18.74 17.47 17.38 17.75 

Project Cost* (Rs Cr) 184.88 169.63 126.23 116.41 116.81 118.72 

Cost/MW (RsCr) 0.77 1.41 1.40 3.47 2.29 3.97 

*1 Euro= Rs67.07 

Note: As per decision taken by Department of External Affairs (DEA), Govt. of India, in the meeting held in New 

Delhi on dated 10/10/2012, three tunnel based HEP’s i.e. Chibro, Khodri and Tiloth HEPs may not be funded by 

KfW for RMU works. However communication from KfW in this respect has not yet been received. Accordingly, 

RMU of these projects may be undertaken under National Competitive Bidding with Domestic financing after 

consent of Government of Uttrakhand is conveyed to DEA and subsequently their formal approval is received by 

UJVNL. 

313


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 

316

SMALL HYDRO PROJECTS (SHP) 

There are 10 SHPs under construction having installed capacity of 58.00 MW in district 

Rudraprayag, Pauri, Uttarkashi and Pithoragarh. These projects are funded by ADB and 

NABARD. The list alongwith proposed fund requirement of these SHPs are enclosed as 

Annexure-A. 

There are 12 SHPs under investigation and planning (I&P) stage having installed 

capacity of 122.6 MW. DPR of Suringad-II and Bhilangna-IIA have been prepared and 

tenders have been invited which may be awarded during 2012-13 and 2013-14. The 

DPR of rest of the 10 SHPs are expected to be completed by June 2013. The list 

alongwith proposed fund requirement of SHPs are enclosed as Annexure-B. 

Apart from the above there are 32 SHPs, constructed in the time of erstwhile UPJVNL 

and handed over to Nigam Annexure-C. 22 no. of these SHPs are running and 10 

under closed conditions. The total installed capacity of these SHPs is 24.55 MW. In 

compliance to orders of Uttarakhand Government vide letter no. 80@fu-l-@Á-l&eq e- 

@2012 fnukad 12.12.2012 (Annexure), the SHPs below 3 MW capacity are to be 

handed over to UREDA. The process of handing over of SHPs below 3 MW capacity 

has been initiated. The list of plant, machinery, residential and non-residential building, 

furniture, land etc. is under preparation.

KALIGANGA-I SMALL HYDROELECTRIC PROJECT (4 MW) 

Kaliganga-I Small Hydro Electric Project is having an installed capacity of 4000 KW 

with two (02) units of 2000 KW each. The project is being financed by ADB. The 

contract was awarded on 07.11.2007 and completion as per Contract was 6th Feb. 

2010. This project has been commissioned on 18/19 July 2012 and now in 

operation. The reasons for delayed commissioning of the project were due to (i) 

Dispute in demarcation of Forest land, (ii) Design changes in the project took 

considerable time,(iii) Road Blockage due to cloud burst in rainy season affected 

progress of work at the project,(iv) Heavy monsoon and cloud bursting and 

washing away of T &P of contractor,(v)Difficulty being faced by the contractors in 

transporting material, machines and equipment to site due to damaged approach 

road near Kalimath Temple,(vi) Hindrance created by local villagers regarding their 

demands varying from time to time,(vii) Land issues with local natives for 

transmission towers in Rudraprayag District. 

KALIGANGA-II SMALL HYDROELECTRIC PROJECT (6 MW) 

Kaliganga-II Small Hydro Electric Project is having an installed capacity of 6000 

KW with two (02) units of 3000 KW each. The project is being financed by ADB. 

For the project two contracts were awarded i) Civil & ii) E &M. Civil Contract was 

signed on 04.04.2008. The effective date of start was 2 nd May 08. The duration of 

contract was kept for two years with the due date of completion as 1 st May 2010. E 

&M Contract was signed on 16.06.2008 for Design, Supply, Installation, 

Commissioning and Testing of Electromechanical work of Kaliganga-II SHP. The 

effective date of start was 5 th July 08. The duration of contract was kept for two 

years with the due date of completion as 04 th July 10. The project could not be 

completed in time due to various reasons as mentioned below and now the 

commissioning of project is expected by Dec. 2013. The reasons for delay are 

mainly due to (i)Design was changed due to changes in gross head which took 

considerable time in finalization of the layout,(ii) The PWD Road to this project site 

was damaged due to frequent landslides. Due to this, difficulty was faced in 

supplying the material to site.(iii) Limited use of explosive due to tunnel location in 

the near vicinity of village.(iv) Increase in scope of work, change proposal.(v)Heavy 

monsoon and cloud bursting and washing away of T &P of contractor.(vi) Difficulty 

being faced by the contractors in transporting material, machines and equipment to 

site due to damaged approach road. (vii) Hindrance created by local villagers 

regarding their demands varying from time to time. 

MADHYAMAHESHWAR SMALL HYDROELECTRIC PROJECT (15 MW) 

Madhyamaheshwar Small Hydro Electric Project is having an installed capacity of 

15 MW with three units of 5MW each. Previously the capacity was 10MW which 

was enhanced to 15MW. The project is being financed by ADB.

For the project, Contract was signed on dated 07.11.2007. The effective date of 

start was 7 th Feb. 2008. The duration of contract was kept as two years with the 

due date of completion as 6 th Feb. 2010 for 10MW SHP. The capacity of the 

project was further enhanced to 15.00 MW and the modified contract agreement 

for 15 MW was signed on 11.03.2010 with modified completion period as 

10.08.2011. Works on the project slowed down due to various reasons, some of 

these are (i) Hindrance created by local villagers regarding their demands varying 

from time to time, (ii) PWD Road to this project site was damaged due to frequent 

landslides. Due to this difficulty was faced in supplying the material to site.(iii) 

Design changes in the project took considerable time.(iv)Considerable increase in 

scope of work (from 10 MW to 15 MW).(v) Unusual heavy rains in 2010 & 2011 

and cloud burst in Ukhimath in 2012. 

All out efforts are being made to commission the project in 2014-15 as per revised 

schedule, if there is no hindrance from any corner and uncertain geological 

condition in the tunnel or natural flood condition. 

KALDIGAD SMALL HYDROELECTRIC PROJECT (9 MW) 

Kaldigad Small Hydro Electric Project is having an installed capacity of 9 MW with 

two (02) units of 4.5 MW each. The project is being financed by ADB. 

For the project two contracts were awarded (i) Civil & ii) E &M. Civil Contract was 

signed on 24.12.2008 and the E&M contract was signed on 16.10.2008. The total 

duration of the contract was kept for two years as such the date of completion was 

2.12.2010, but civil contract has been cancelled due to poor performance of the 

contractor and new tenders shall have to be invited. This project has damaged due 

to devastating flood caused by cloudburst in District Uttarkashi on 03.08.2012, now 

action on the project is being taken as per recommendations of the Technical 

Expert Committee constituted for suggesting remedial measures. Some additional 

land may also be required. The commissioning of project is expected by Aug. 

2015, if there is no hindrance from any corner and uncertain geological condition in 

the tunnel and additional land is transferred at an early date. 

SOBLA-I SMALL HYDROELECTRIC PROJECT (8 MW) 

Sobla-I Small Hydro Electric Project is having an installed capacity of 8 MW with two 

(02) units of 4.0 MW. The Civil works are being funded by NABARD and E &M 

works are being funded by ADB. All out efforts are being made to commission the 

project upto June 2013 if there is no hindrance from any corner.

ASIGANGA-I SMALL HYDROELECTRIC PROJECT (4.5 MW) 

Asiganga-I Small Hydro Electric Project is having an installed capacity of 4500 kW 

with two (02) units of 2250 kW. The project is being financed from NABARD, 

MNRE & GoU Equity. 

Tenders in different packages were invited for the SHP and the original date of 

completion was 2005-06, the project could not be completed upto the expected 

date of completion due to some change in civil structures. The revised date of 

commissioning was Nov. 2012, but there were heavy damages in civil structures 

due to devastating flood caused by cloudburst on 03.08.2012. A Technical Expert 

Committee was formed by MD UJVNL for study and suggesting remedial 

measures for small hydro power projects damaged due to flood caused by 

cloudburst in District Uttarkashi on 03.8.2012. Works on the project slowed down 

due to various reasons. Some of these are: (i) Allotment of land for compensatory 

afforestation in District Uttarkashi (ii) Due to introduction of tunnel in place of open 

power channel, previous tenders were cancelled and fresh tenders were invited, (iii) Land 

slide in Power Channel alignment.(iv) Need for construction of Tunnel in place of 

Power channel.(v) The agreements of some of the contractor were cancelled due 

to their non responsive nature, hence construction activity took considerable 

time.(vi) Public agitations resulted in disruption of work.(vii) Design changes in the 

project took considerable time. (viii) Local problems for their demand varying time 

to time mainly for permanent employment in UJVNL and also development work in 

project affected villages.(ix) Three accidents during channel excavation. 

All out efforts are being made to commission the project upto October 2014, if 

there is no hindrance from any corner 

ASIGANGA-II SMALL HYDROELECTRIC PROJECT (4.5 MW) 

Asiganga-II Small Hydro Electric Project is having an installed capacity of 4500 kW 

with two (02) units of 2250 kW each. The project is being financed from NABARD, 

MNRE & GoU Equity. 

Tenders in different packages were invited for this SHP and the original date of 

completion was 2005-06 which was extended upto Oct. 2011 as per revised 

capacity. Works on the project slowed down due to various reasons. Some of 

these are: (i) Delay in allotment of land for compensatory afforestation in District 

Uttarkashi (ii) Due to introduction of tunnel in place of open power channel, the 

previous tenders were cancelled and fresh tenders were invited, (iii) The 

agreements of some of the contractor were cancelled due to their non responsive 

nature , hence construction activity took considerable time to start the works,(iv) 

The capacity of the project was enhanced from 3.0 MW to 4.5 MW , hence design 

parameters were changed, (v)Public agitations resulted in disruption of work, (vi) 

Design changes in the project took considerable time,(vii) Local problems for their 

demands varying time to time mainly for permanent employment in UJVNL and 

also development work in project affected villages caused delay,(viii) In view of

accidents at adjacent project Asiganga-I , the construction activities were stopped 

during rains 

The project has damaged due to devastating flood caused by cloudburst in District 

Uttarkashi on 03.08.2012, now action on the project is being taken as per 

recommendations of the Technical Expert Committee constituted for suggesting 

remedial course of action for small hydro power projects damaged due to 

cloudburst in District Uttarkashi on 03.8.2012 

All out efforts are being made to commission the project upto October 2014, if 


DUNAO SMALL HYDROELECTRIC PROJECT (1.5 MW) 

Dunao Small Hydro Electric Project is having an installed capacity of 1.5 MW with 

two (02) units of 750 kW project. The project is being financed from NABARD, 

MNRE & GoU Equity 

Tenders in different packages were invited for this SHP and the original date of 

completion was 2007-08, the project could not be completed upto the expected 

date of completion due to various reasons. Some of these are: (i) Necessity of retendering 

due to higher rates in original tenders. (ii) Due to remote site condition, 

the response of the bidder was poor, so tendering process took long time.(iii) 

Project was stopped as per directions of BOD from 11.02.2010 to 15.09.2010 due 

to shortage of funds.(iv) Slow progress of Civil works due to non-availability of site 

access.(v) Adverse working conditions & site remoteness even labourers are not 

staying at Project site.(vi) Considerable time taken in making approach to project 

site.(vii) Due to non-performance of Civil Contractor for P.H. Building, the contract 

has been cancelled.(viii) Technical problem for using old machines from another 

SHP for Dunao and necessity of procurement of new machine. 

All out efforts are being made to commission the project upto December 2013, if 


SUWARIGAD SMALL HYDROELECTRIC PROJECT (2.0 MW) 

Suwarigad Small Hydro Electric Project is having an installed capacity of 2 MW 

with two (02) units of 1 MW each. The project is being financed from NABARD, 

MNRE & GoU Equity. The contract agreement for construction of the project was 

signed on 29.09.2011. The completion period was expected by Mar. 2013, but in 

the project there is problem of land. The land of the SHP was included in land case 

of Pala Maneri. With closure of Pala Maneri, the forest department has not allowed 

to work on Suwarigad SHP, now land case is being presented to competent 

authority for approval.

All out efforts are being made to commission the project upto December 2013, if 

there is no hindrance from any corner and the land case is approved at the 

earliest. 

LIMCHAGAD SMALL HYDROELECTRIC PROJECT (3.5 MW) 

Limchagad Small Hydro Electric Project is having an installed capacity of 3500 kW 

with two (02) units of 1750 kW each. The project is being financed by NABARD, 

MNRE & GoU Equity. The contract agreement for construction of the project was 

signed on 29.09.2011 and the commissioning is expected by March 2014, but in 

the project there is requirement of extra land for which approval is being taken from 

competent authority. 

All out efforts are being made to commission the project upto March 2014, if there 

is no hindrance from any corner

Annexure-A 

Business Plan for Small Hydro Projects Under Construction 

S.No. 

Name of Project 

Capacity 

(MW) 

Expected 

Commissioning 

of Project 

Project Cost Proposed Fund Requirement (Rs in Crores) 

(as per DPR) 

(Rs in upto 2012- 

Crores) 13 

2013-14 2014-15 2015-16 2016-17 

1 Kaliganga-I 4.00 Commissioned 32.22 29.25 2.97 

2 Sobla-I 8.00 Jun. 2013 36.26 19.00 11.00 

3 Kaliganga-II 6.00 Dec. 2013 68.93 33.53 10.00 6.89 

4 Dunao 1.50 Dec. 2013 31.20 7.85 10.00 3.12 

5 Madhyamaheshwar 15.00 2014-15 120.21 31.06 16.50 25.50 3.01 

6 Suwarigad 2.00 Mar. 2014 16.06 1.75 5.00 2.41 0.80 

7 Limchagad 3.50 Mar. 2014 26.59 2.68 5.00 3.99 1.33 

8 Asiganga-I 4.50 Oct. 2014 40.40 26.26 3.50 6.06 2.02 

9 Asiganga-II 4.50 Oct. 2014 36.97 17.85 10.00 5.55 1.85 

10 Kaldigad 9.00 Aug. 2015 76.19 32.29 5.00 11.46 11.43 3.81 

Total 58.00 485.03 201.52 78.97 64.98 20.44 3.81 

Note:- We are trying hard to complete these projects in time ,but the schedule may change due to uncertainty involved in geological conditions, change 

in profile in bed level of river caused by devastating flood due to cloud burst in Aug. 2012 and approval of land in case of Kaldigad,Asiganga_I,Asiganga- 

II ,Suwarigad and Limchagad SHP.

Annexure-B 

Business Plan for Small Hydro Projects Currently Under Investigation and Planning 

S.No. 

Name of Project 

Capacity 

(MW) 

Expected 

Award of 

Contract 

Expected 

Commissionin 

g of Project 

Project 

Cost 

(Rs in 

Crores) 

Proposed Fund Requirement (Rs in Crores) 

2013-14 2014-15 2015-16 2016-17 2017-18 2018-19 2019-20 

1 Suringad-II 5.00 Mar-13 Sep-16 49.60 4.96 9.92 14.88 14.88 4.96 

2 Urgam-II 5.00 Sep-13 Sep-16 47.00 4.70 9.40 14.10 14.10 4.70 

3 Guptkashi 1.30 Mar-14 Sep-16 8.00 0.80 3.20 3.20 0.80 

4 Chamoli 0.80 Jun-14 Jun-17 3.20 0.32 0.64 0.96 0.96 0.32 

5 Sonegad 7.50 Jun-14 Jun-17 65.00 6.50 13.00 19.50 19.50 6.50 

6 Tankul 12.00 Sep-14 Sep-17 96.00 9.60 19.20 28.80 28.80 9.60 

7 Bhilangna-II A 24.00 Sep-13 Sep-17 233.81 11.69 23.38 58.45 58.45 58.45 23.38 

8 Painagad 9.00 Mar-14 Sep-17 77.57 3.88 19.39 23.27 23.27 7.76 

9 Asiganga-III 9.00 Sep-13 Sep-17 93.34 4.67 23.34 28.00 28.00 9.33 

10 Pilangad-II 4.00 Dec-14 Dec-17 24.00 1.20 3.60 8.40 8.40 2.40 

11 Bhilangna-II B 24.00 Jun-14 Mar-18 227.93 11.40 34.19 45.59 56.98 56.98 

12 Bhilangna-II C 21.00 Sep-14 Jun-18 199.50 9.98 29.93 39.90 49.88 49.88 19.95 

Total 122.60 1124.95 21.35 91.04 233.91 285.05 284.70 166.15 19.95

1. Pathri Hydroelectric Project (20.4 MW) 

Background: 

The power station is located on the Upper Ganga Irrigation canal that takes off 

from the Bhim goda Barrage near Haridwar at a distance of 13 km downstream 

of Haridwar. The power plant was commissioned in the year 1955. The surface 

Power House comprising 3 units of 6.8 MW each with Kaplan turbines of 8400 

HP output is located on the unlined irrigation canal and the water is utilized for 

the irrigation purpose in the command area of the canal. 

Project Cost without IDC : 

INR 92.86 Crore 

Project Cost with IDC : INR 105.63 Crore 

Cost Breakup: 

E&M Works : INR 80.96 Crore 

HM Works : INR 4.92 Crore 

Civil Works : INR 2.41 Crore 

Establishment : INR 3.05 Crore 

Ordinary T&P : INR 0.77 Crore 

Loss on stock : INR 0.0055 Crore 

Receipt & recovery : INR -0.03 Crore 

Audit & Account : INR 0.77 Crore 

Average Generation as Per RMU DPR (Post Tehri) : 

90 MU 

Generation after RMU : 155.6 MU

Status of RMU Works: 

‣ Contract Signed on 9th March 2010 

‣ Machine # 3 given for reverse engineering on 11th May 2010 and 

after taking the measurements the machine was put on the bars on 

2nd July 2010. 

‣ After engineering & change request acceptance Machine # 3 was 

given for extensive RMU on 6th Oct 2011 

Commissioning Schedule: 

Machine # 3 : From 6th Oct 2011 to 30th April 2013 

Machine # 1 : From 1st March 2013 to 29th Nov 2013 

Machine # 2 : From 1st April 2013 to 30th Nov 2013 

Financing of Capital Expenditure: 

The Project is being financed with the Debt: Equity ratio of 70:30. The funding 

is being done through PNB. 

MNRE Grant : INR 12.50 Crore 

Phasing of Capital Expenditure : 

Year 2010-11 2011-12 2012-13 2013-14 

Capital 

Expenditure 

(Rs Cr) 

11.14 5.85 23.22 52.65

2. Mohd. Pur Hydroelectric Project (9.3 MW) 

Background: 

Mohammadpur Power House has been constructed on upper Ganga Canal at 

49.5 km downstream of Mayapur Head Works, Hardwar. The power house, 

which has 3 units of 3.1 MW each, was commissioned in the year 1952. All the 

mechanical equipments were supplied by M/s Boving and Co., England and 

electrical equipments by M/s British Thomson Houston, (BTH) England. 

Project Cost without IDC : INR 67.39 Crore 


Cost Breakup: 





Ordinary T&P : INR 0.64 Crore 

Loss on stock : INR 0.0.0077 Crore 

Receipt & recovery : INR -0.013 Crore 


Average Generation as Per RMU DPR (Post Tehri) : 40.44 MU 

Generation after RMU : 64.92 MU 


‣ Contract Signed on 6 th April 2010 

‣ Machine # 2 given for given for extensive RMU on 6 th June 2010 

‣ All works related to switchyard, control room & switchgear 

completed in Nov 2011.

‣ Machine # 2 was commissioned and connected to Grid on 30 th April 

2012 

‣ Machine # 1 was given for extensive RMU on 1 st May 2012 

‣ Machine # 3 was given for extensive RMU on 15 th Oct 2012 


Machine # 2 : From 6 th June to 30 th April 2012 

Machine # 1 : From 1 st May 2012 to 30 th April 2013 

Machine # 3 : From 15 th Oct 2012 to 5 th June 2013 


The Project is being financed with the Debt: Equity ratio of 95:5. The funding is 

being done through NABARD. 

MNRE Grant 

: INR 6.65 Crore 


Year 2010-11 2011-12 2012-13 2013-14 

Capital 

Expenditure 

(Rs Cr) 

10.78 17.94 21.40 17.27

3. Galogi Hydroelectric Project (3 MW) 

Background: 

One of the oldest running power house (commissioned in 1907) in the country and 

therefore a part of Indian National Heritage, Galogi Hydropower Station is located 

on river Kyarkuli near Mussoorie – about 22 km from Dehradun. It has 2 machines 

of 500 kW each and 2 machines of 1000 kW each. However, the historical 

capacity of this scheme is 2381 kW based on available discharge to the 

machines. 2 units of 500 kW were installed in Phase-I in the year 1907 and 2 units 

of 1000 kW in 1933 in Phase-II. Mussoorie was India’s second and Northern 

India’s first region to generate electricity. 

Project Cost without IDC : INR 20.14 Crore 


Cost Breakup: 





Ordinary T&P : INR 0 Crore 

Loss on stock : INR 0.0.02 Crore 

Receipt & recovery : INR 0 Crore 


Average Generation as Per DPR : 3.07 MU 

Generation after RMU : 8.28 MU 


‣ Contract for penstock works signed in Jan 2009 

‣ Contract for E&M works signed in July 2009

‣ Penstock work completed on 30 th April 2012 

‣ Machine # 1 connected to grid on 18 th Feb 2012 

‣ Machine # 4 connected to grid on 7 th Aug 2012 

‣ Due to damage of 6.6 / 33 kV transformer at Anarwala S/S of UPCL 

the machines are being operated presently in standalone mode 

with a maximum demand of 200 kW at Barloganj. 

‣ Machine # 2 shall be taken under RMU after commissioning of DG 

set. 


Machine # 1 : From 7 th Aug 2009 to 18 th Feb 2012 

Machine # 2 : 

From 30 th Jan 2013 to 30 th April 2013 (subject to 

Installation of DG set) 

Machine # 4 : From 7 th Aug 2009 to 7 th Aug 2012 


The Project is being financed with the Debt: Equity ratio of 70:30. The funding 

is being done through PNB. 

MNRE Grant : INR 3.5 Crore 


Year 2007- 

08 

2008- 

09 

2009-10 2010- 

11 

2011-12 2012-13 2013- 

14 

Capital 

Expenditure 

(Rs Cr) 

0.168 0.336 1.846 2.685 5.035 5.035 5.035

CAPITAL EXPENDITURE FOR RMU OF PATHRI, MOHD. PUR & GALOGI SHPs 

Rs. Crores 

PROJECT NAME 


FY 2007-08 FY 2008-09 FY 2009-10 FY 2010-11 FY 2011-12 FY 2012-13 FY 2013-14 

RMU OF SHPs 

GALOGI 0.17 0.34 1.85 2.69 5.04 5.04 5.04 

PATHRI 11.14 5.85 23.22 52.65 

MOHD.PUR 10.78 17.94 21.40 17.27 

TOTAL OF RMU OF SHPs 0.17 0.34 1.85 24.61 28.83 49.66 74.96

UJVN Ltd. 

Manpower Planning for the control Period 

1. Permanent Strength – Sanctioned and Actual at present – Annexure 1 

2. New Projects including Green Site Projects – as sanctioned by GoU – 213 Numbers – 

Annexure 2 

3. Vyasi Project - as sanctioned by GoU – 199 numbers – Annexure 3 

4. R.M.U. structure created to meet Renovation, Modernization and Up-gradation of existing 

Power Houses – Annexure 4 

5. S.H.P. (Small Hydro Projects) – Structure created – Annexure 5 

6. In order to cope up with the manpower requirement of New Projects and replacement of 

retired employees, the following steps have been taken during the year 2012-13 

6.1 Employees joined during 2012-13 :- 

Sl.No. Name of the post at Induction Level Number of persons 

recruited / joined 

1 Junior Engineer (Trainee) - Civil 68 

2 Asstt. Engineer (Trainee) - Civil 13 

3 Junior Engineer (Trainee) – E&M 28 

4 Accounts Officer 09 

5 Manager (Environment) 01 

Total 119 

6.2 Appointment Offers issued and number of employees expected to join :- 

Sl.No. Name of the post at Induction Number of persons Remarks 

Level 

recruited / joined 

1 Junior Engineer (Trainee) - Civil 19 To join on 28/01/13 

2 Asstt. Engineer (Trainee) – E&M 23 To join on 29/01/13 

3 Asstt. Engineer (Trainee) – Civil 04 To join by 01/03/13 

4 Junior Engineer (Trainee) – 

E&M 

30 Appointment Offers to be 

issued after verification of 

documents to join by 

31/03/13 

5 Asstt. Engineer (Trainee) – Civil 03 Appointment Offers to be 

issued to join by 31/03/13 

Total 79 

6.3 Recruitment planned for ministerial cadre during 2013 -14 

Written test organized by Uttarakhand Board of Technical Education on 04/11/2012 

for recruitment for following posts – expected to join during the year 2013-14 

‣ Stenos 

– 85 numbers 

‣ Office Asstt. Grade III (Clerical Cadre) – 68 numbers 

‣ Asstt. Store Keepers 

– 21 numbers 

‣ Asstt. Accountant 

–06 numbers 

Total 

- 180 numbers

6.4 Recruitment planned for Technical / Operating / Officer cadre during 2013-14 

Name of the post Number of posts Remarks 

T.G. II (Elect. & Mech) 123 Advertisement being released by 

Draughtsman 50 Uttarakhand Board of technical 

Education 

Personnel Officer 03 Advertisement being released by 

Geologist 02 UJVN Ltd. 

Asstt. Company Secretary 01 

Sr. Geologist 01 In process on Deputation basis 

Total 180 

6.5 Additional manpower of AEs (T) and JEs (T) will also be met – during the year 2013-14 

after sanction from GoU is received for additional posts to be appointed after 28.02.13 

(Annexure 2) as the recruitment process has already been finalized for one year. 

7. For optimum utilization of manpower and succession planning, the following steps to be 

taken – 

7.1 Defining of Job responsibilities, role/profile succession planning keeping in view 

structure of New Projects, SHPs/ O&M Projects/ RMU Projects, in consultation with 

concerned Director / E.D. 

7.2 Training of newly recruited Engineers at SJVNL/BBMB/NHPC/THDC/IITs 

7.3 In-house and on the job training of newly recruited engineers / staff in a systematic 

manner. 

7.4 Posting of Engineers in new projects to be done in a phased manner. 

7.5 As per Government instructions, Class IV posts are to be managed by way of 

outsourcing.

Business Plan for UJVNL - UJVN Limited Dehradun...

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